No.IA-J-11011/108/2019-IA-II(I)

Goverment of India

Minister of Enviroment,Forest and Climate Change

Impact Assessment Division

***

Indira Paryavaran Bhavan,

Vayu Wing,3rd Floor,Aliganj,

Jor Bagh Road,New Delhi-110003

26 Apr 2019

To,

         M/s M/s Vedanta Limited(Division Cairn Oil & Gas)

         DLF Atria, Phase 2, Jacaranda Marg, DLF City,

         Gurgaon-122002

         Haryana

Tel.No.0124-4594176; Email:mayank.sharma@cairnindia.com

Sir/Madam,

                      This has reference to the proposal submitted in the Ministry of Environment, Forest

and Climate Change to prescribe the Terms of Reference (TOR) for undertaking detailed EIA

study for the purpose of obtaining Environmental Clearance in accordance with the provisions of

the EIA Notification, 2006. For this purpose, the proponent had submitted online information in the

prescribed format (Form-1 ) along with a Pre-feasibility Report. The details of the proposal are

given below:

1. Proposal No.:                              IA/GJ/IND2/100119/2019

2. Name of the Proposal:              

Onshore Oil and Gas Exploration and Appraisal

in CB-ONHP-2017/10 block in Banaskantha

District of Gujarat and Jalore District of

Rajasthan.

3. Category of the Proposal:         Industrial Projects - 2

4. Project/Activity applied for: 1(b) Offshore and onshore oil and gas

exploration, development & production

5. Date of submission for TOR:      23 Mar 2019

NET Payment Receipt

Address : , BANASKANTHA DISTRICT (2100 sq.km.) OF GUJARAT \u0026 JALORE DISTRICT (666 sq.km.) OF RAJASTHAN, , NAVAPURA, Palanpur Pin : 385330

Bank Details

Transaction No

Application: 164773(ECC)-dd/MM/yyyy

SBI-CHB7536914

QSBI7968421758

PCB ID: 73767-VEDANTA LIMITED (Division: Cairn Oil and Gas) - CB-ONHP-2017/10 Block

Payment Id 234251

Payment Date 11/09/2019

Date : 11/09/2019

Paid Amount 700000

Status Success

Remarks Completed successfully.

Type

Referance No

MIS Date

164773 (Environment Clearance)

EC -ECC-CCA

-

Pre-Feasibility Report

For

Onshore Oil and Gas Exploration and Appraisal in Block CB-ONHP-2017/10 in Banaskantha District of Gujarat & Jalore

District of Rajasthan

VEDANTA LTD. (CAIRN OIL & GAS)

March,2019

2

Table of Contents

1. Executive Summary ...................................................................................................................... 4

1.1 Project Details .............................................................................................................................. .4

1.2 Site Analysis ………………………………………….…………………….………………………………………………………4

1.3 Water and Power Requirement …………….…………………………………….………….…………………………..5

1.4 Pollution control measures........................................................................................................... 5

1.4.1 Pollution Control measures during Seismic Operations ............................................................... 5

1.4.2 Pollution Control measures during Drilling Operations ............................................................... 5

1.5 Project schedule and cost estimate .............................................................................................. 6

1.6 Employment Generation .............................................................................................................. 6

1.7 Rehabilitations and Resettlements ............................................................................................... 6

2. Introduction of the project ........................................................................................................... 7

2.1 Identification of the project....................................................................................................7

2.2 Brief description of nature of the project...............................................................................7

2.3 Need for the project and its importance to country and region............................................7

2.4 Demand-supply Gap...............................................................................................................8

2.5 Import versus indigenous production and export………………………………………………………………8

2.6 Domestic Markets……………………………………………………………………………………………………………..8

2.7 Employment generation…………………………………………………………………………………………………….8

3 Project Description ....................................................................................................................... 9

3.1 Type of project .............................................................................................................................. 9

3.2 Location with co-ordinates ........................................................................................................... 9

3.3 Details of alternate site considered and the basis of selecting the proposed site……….......12

3.4 Size/ magnitude of operation……………………………………………….…………………………………………12

3.5 Project description with process details ..................................................................................... 12

3.6 Raw materials required and source ............................................................................................ 25

3.7 Resource optimization/ recycling and reuse envisaged in the project……………………………...25

3.8 Water and power requirement .................................................................................................. 26

3.9 Quantity of waste to be generated and its disposal ................................................................... 27

3.10 Schematic of Feasibility Drawing………………………………………………………………………………………28

4. Site Analysis ................................................................................................................................ 29

4.1 Connectivity ................................................................................................................................ 29

4.2 Land form, land use and land ownership ................................................................................... 29

4.3 Topography ................................................................................................................................. 29

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4.4 Existing land use pattern and relative location of protected areas ........................................... 29

4.5 Existing infrastructure / Industries ............................................................................................. 29

4.6 Soil Classification ........................................................................................................................ 30

4.7 Climate data from secondary sources ........................................................................................ 31

4.7.1 Wind ........................................................................................................................................... 31

4.7.2 Storms and cyclones ................................................................................................................... 31

4.7.3 Rainfall ........................................................................................................................................ 31

4.7.4 Temperature and humidity......................................................................................................... 31

5 Planning Brief .............................................................................................................................. 32

5.1 Planning concept ........................................................................................................................ 32

5.2 Population projection ................................................................................................................. 32

5.3 Land use planning (break up along with green belt, etc) ........................................................... 32

5.4 Assessment of Infrastructure demand ....................................................................................... 32

6. Proposed Infrastructure ............................................................................................................. 32

7. Rehabilitation and Resettlement……………………………………………………………………………………32

8. Project schedule and cost estimate ............................................................................................ 33

8.1 Project schedule ......................................................................................................................... 33

9. Analysis of Proposals (Final Recommendations) ........................................................................ 33

List of Tables

Table-1: Co-ordinates of Block CB-ONHP-2017/5 boundary (as per RSC)............................................11

Table-2: Co-ordinates of Block CB-ONHP-2017/10 boundary in Banaskantha District of

Gujarat.................................................................................................................................................12

Table-3: Co-ordinates of Block CB-ONHP-2017/10 boundary in Jalore district of Rajasthan (as per

RSC) ………………………………………………………………………………………………………………………………..……….......13

Table4: Tentative well co-ordinates to be drilled in block CB-ON-HP

2017/10…………………………………………………………………………..…………………………………………………………….18

Table 5: Details of the drilling rig ……………………………………………………………….….……………..………..……..20

Table 6: Details of DG sets of Onshore Drilling Activity ……………………………….…………………..…………….27

Table 8: The expected waste generation from well drilling)……………………….………….…........……….……28

Table 9: Climatological Summary at IMD Deesa (1961 – 1990)…………….………………………………………...31

Table 10 : Climatological Summary at IMD Barmer (1961 – 1990)…………………………………………….…….31

4

List of Figure

Figure-1.a: Location map of block CB-ONHP-2017/10 with state and district boundary…………………10

Figure-1.b: Location map of block CB-ONHP-2017/10 with state and district boundary……….……….12

Figure 2: Various phases of the drilling activities……………………………………………..……………………………15

Fig 1 A typical model onshore drilling process………………………………………………………….……………………15

Figure-4. Google map with Tentative Location of proposed wells on satellite map………………………..16

Figure-5: Toposheet map with Tentative Location of proposed wells on satellite map……….………17

Figure-6: Typical configuration of a Drilling Rig…………………………………………………………………………21

Figure-7: Flow Chart for Drilling Mud & Solid Discharge……………………………………………………………22

Figure 8: Schematic for a typical Well Pad…………………………………………………………………………………29

5

1. Executive Summary Vedanta (erstwhile Cairn India Limited merged with Vedanta Limited w.e.f. April 11, 2017, pursuant

to NCLT order dated March 23, 2017) is a globally diversified natural resources company with

interest in Zinc, Iron Ore, Aluminium, Copper, Power and Oil & Gas. Vedanta Ltd. (Cairn Oil & Gas) is

the operator of the Onshore CB-ONHP-2017/10 block. The block covers an area of 2100Sq.Km in

Banaskantha District of Gujarat and 666 Sq. km in Jalore District of Rajasthan. Vedanta Ltd. has been

granted with an exploration and production license by Government of India under the Revenue

Sharing Contract (RSC) on1st October 2018.

1.1 Project Details

1.1.1 Proposed facilities

Vedanta Limited (Cairn Oil & Gas) proposes to carryout Seismic survey, exploratory including

appraisal well drilling and setting up of Early Production Units (EPUs)/Quick Production Units (QPUs)

and early production in the block CB-ONHP-2017/10.

1.1.2 Justification of the project

The demand for petroleum has recorded a considerable increase over the last few years. There is a

considerable increase in consumption of petroleum products due to the development activities in

the country in the last few years. During the year 2016-17, the consumption of petroleum products

in India was 194.60 MMT with a growth of 5.37% as compared to consumption of 184.67 MMT

during 2015-16. The consumption of petroleum products during April-November, 2017 was at

134.60 MMT i.e. an increase of 3.40% over 130.17 MMT in April-November, 2016. The crude oil

production for the year 2016-17 is at 36.01 Million Metric Tonnes (MMT) as against production of

36.94 MMT in 2015-16, showing a decrease of about 2.53%. Whereas Natural Gas production during

the year 2016-17 is at 31.90 Billion Cubic Meters (BCM) which is 1.09% lower than production of

32.25 BCM in 2015-16. Import of crude oil during 2016-17 was 213.93 MMT valued at 470159 crore

as against import of 202.85 MMT valued at 416579 crore in 2015-16 which marked an increase of

5.46% in quantity terms and 12.86% in value terms as compared to the import of crude oil during

2015-16.

Import of Crude Oil during April-November, 2017 was 144.72 MMT valued at 3,42,673 crore which

marked an increase of 9.31% in quantity terms and 15.32% in value terms as against the imports of

143.81 MMT valued at 2,97,161 crore for the same period of last year. Therefore, India is largely

dependent on import of petroleum goods to meet its requirements. Facing an environment of

increasing consumption, static reserves, increasing imports and increasing costs of crude as well as

decreasing value of the Indian Rupee vis-à-vis the US Dollar, it follows that any accretion of

hydrocarbon reserves in the country, is welcome.

Vedanta’s (Cairn oil & gas) proposed exploratory and appraisal drilling could possibly result in the

discovery of hydrocarbon and in that case, would help in reducing India’s dependence on imports.

1.2 Site Analysis

1.2.1 Climate

The study area experiences a humid and warm sub-tropical climate throughout the year except for a

cold winter in December till February. Hourly micro-meteorological data collected during the pre-

monsoon of Deesa, Gujarat reveals that the pre-dominant wind direction is from North to South with

an average speed of 7.2kmph.Hourly micro-meteorological data collected during the pre-monsoon

6

of Barmer, Rajasthan reveals that the pre-dominant wind direction is from SouthWest to North East

with an average speed of 7.9kmph.

1.3 Water and power requirements

1.3.1 Water Requirement

A. Water Requirement during Seismic Survey

The water requirement is 20-30 m3/day for domestic needs of the temporary campsite and will be

sourced locally through approved authorities.

B. Water requirement during Exploratory and Appraisal well drilling

The most significant requirement of water for drilling activities is for mud preparation. The water

requirement for WBM preparation will be 600-1000 m3/well. The water requirement for SBM

preparation will be 150-300 m3/well. The other requirement approx. 25-50 m3/well/day would be for

drilling activities like engine cooling, floor / equipment / string washing, fire-fighting storage / make-

up. For domestic consumption, approx. 20 - 30 m3/day water will be required during drilling period.

The water requirement will be sourced locally through approved authorities.

1.3.2 Power requirement

A. Power requirement during seismic Survey

The required power supply will be provided from diesel generator of 2X350 kVA.

B. Power requirement during Exploratory and Appraisal well drilling

The power requirement of drill rig will be met by three (03) DG sets (including one as standby)

(3*1000 KVA). The power requirement for drilling camp site will be met by (02) DG Sets (including

one as stand by) (2*350 KVA). The power requirement for Radio Room will be met by (02) DG Sets

(including one as stand by) (2*100kVA).

1.4 Pollution control measures

1.4.1 Pollution Control measures during Seismic Operations

A. Air Emissions and Control Measure

Emissions to air include transient airborne dust raised by construction activities (e.g. preparation of

seismic cut lines and moving vehicles and equipment) and emissions from vehicles and machinery.

These emissions are transient and insignificant nature.

B. Noise Emissions and Control Measure

Noise emissions that could be released during the seismic operations will include those generated by

blasting of charges in shot holes, field machinery (Bulldozer and support vehicles) and generators

and work yard at the camp site. Adequate noise control measures will be taken to minimize the

noise level.

C. Wastes treatment and disposal

The non-hazardous wastes like domestic wastes and effluents, plastics, and paper and disposal

options include, compaction and removal from site and burying (especially for biodegradable

material), or a combination of these activities.

1.4.2 Pollution Control measures during Drilling Operations

A. Air Emissions and Control Measure

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The emissions to the atmosphere from the drilling operations shall be from the diesel engines, and

power generator and temporary from flaring activity (during testing). Appropriate air emission

control measures will be taken.

B. Noise Emissions and Control Measure

The source of noise generation during this phase of operations would be the operation of rig and

diesel generator sets. Besides, certain pumps are expected to be in operation during this phase, for

mud circulation. The noise generation work however is transient and limited to the drilling period

only. Appropriate control measures will be taken to minimize exposure of noise to drilling personnel.

C. Waste treatment and disposal

Spent WBM mud 250-500 tons/well will be generated at site during drilling operations. This will be

stored in well-designed HDPE line pit.

Drill cutting associated with WBM will be 250-750 tons/well and drill cutting associated with SBM

will be 500-1500 tons/well. Sludge containing oil & other drilling wastes will be 250-500 tons/well.

Used /waste Oil – During the drilling approx. 1-2 tons/well of spent oil will be generated. This oil

shall be sent to authorized recyclers.

Domestic waste of 25-30 kg/day/well shall be generated at site, which will be segregated at source

(Organic / Inorganic) and disposed accordingly.

All kinds of waste will be disposed in accordance with the requirement of CPCB/RSPCB.

D. Waste water Treatment

The drilling waste water will be treated suitably.

1.5 Project schedule and cost estimate

Vedanta Ltd. (Cairn Oil and Gas) has planned to carry out the proposed project activities in theCB-

ONHP-2017/10 Block over a period of 10-12 years.

The estimated cost of the project is given below:

1) Physical Surveys Cost estimated to be approximately INR 65.82 Crore.

2) Average Cost per well for exploratory & appraisal well drilling is estimated to be INR 14 Crore.

3) Average cost of a QPF (Quick Processing Facility) is estimated to be INR 44.13 Crore.

1.6 Employment Generation

The seismic survey is expected to take about 6 to 8 months and will require a crew of approximately

300 to 500 persons. And most of the workforce will be fromlocal/nearby areas. During the site

preparation for drilling, approximately 30-35 workmen will be employed per drill site. During the

drilling phase, about 50 workmen per shift will be working on site. This will include technical experts,

who will be responsible for various drilling related activities and some technical manpower engaged

are either from Vedanta Limited or contractor’s crew as applicable. It is anticipated that, at any given

time, there will be about 80-100 personnel working on site including technical staff, drilling crew,

security staff etc. In case of commercial discovery of oil and gas additional manpower will be

employed for building of production facilities and laying of pipelines.

1.7 Rehabilitations and Resettlements

For exploration, appraisal and production activities, the project does not envisage any R & R of the

project, since the land requirement would be very less and on temporary short term lease and away

8

from the settlements. If the identified lands are of private landowners then land lease mode will be

applied and in case of govt. land, land allotment from Govt. to be applied. Initially temporary short

term lease will be taken for 3 - 5 years for exploration purpose and in case of commercially viable

discovery of hydrocarbon resources; the land lease would be converted into long term lease up to

life of the project.

For sites selected having settlements if any, Resettlement & rehabilitation (R&R) plan will be

developed and implemented as per the applicable State/ Central Govt. policy. Compensation to

affected landowners for any loss of land, Cairn will ensure the livelihood of local community, if any

affected by the proposed land take, are identified and compensated through adequate

compensation and other livelihood restoration activities directly or indirectly through CSR activities.

2. Introduction of the project

2.1 Identification of the project

Vedanta Ltd (Cairn Oil & Gas) has been awarded the CB-ONHP-2017/10 hydrocarbon block under the

OALP (Open Acreage Licensing Policy) by MoP&NG, Govt. of India. RSC (Revenue Sharing Contract)

has been signed between Vedanta Ltd and MoP&NG on 1st October, 2018 for the exploration and

exploitation of hydrocarbons. Vedanta Ltd (Cairn Oil & Gas) proposes to carry out exploration

(including seismic surveys, exploratory and appraisal well drilling) and early production of oil and gas

in the block. In case of a discovery (ies), the exploratory and appraisal well(s) will be tested for

extended duration by flowing hydrocarbons to ascertain the reservoir parameters and assess the

quality and commercial viability. Moreover, in case of commercially viable discovery (s) of

hydrocarbons in the block and having established the size of the hydrocarbon field (s), field will be

immediately brought into early production of crude oil and associated gas using some of the

successful exploratory/ appraisal wells by setting up of temporary and mobile Early Production Units

(EPUs)/ QPUs (Quick Production Units) for the processing of produced well fluids.

2.2 Brief description of nature of the project

The proposed project is green field in nature. The project is an oil and gas exploration and early

production project.

2.3 Need for the project and its importance to country and region

India is largely dependent on import of petroleum goods to meet its requirements. Facing an

environment of increasing consumption, static reserves, increasing imports and increasing costs of

crude as well as decreasing value of the Indian Rupee vis-à-vis the US Dollar, it follows that any

accretion of hydrocarbon reserves in the country, is welcome.

Vedanta’s proposed exploratory drilling project could possibly result in the discovery of hydrocarbon

and subsequent development and production would help in reducing India’s dependence on

imports. Consequently, the need for the project is evident. The proposed project would also

contribute to the state Governments in terms of royalty through the mining lease. Additionally the

proposed project would generate direct and indirect employment in the region.

2.4 Demand-supply Gap

9

As on 1.4.2017, In-place hydrocarbon volume of 10454 million tonnes of oil and oil equivalent gas

could be established through exploration by ONGC, OIL and Private/JV companies. So, about 75% of

resources are under “yet to find” category. Out of 10454 MMT of oil and oil equivalent gas of In-

place volumes, the ultimate reserves which can be produced are about 4017 MMT of oil and oil

equivalent gas since inception. The balance recoverable reserves are of the order of 1787 MMT of oil

and oil equivalent gas.

2.4.1Production and Consumption

The crude oil production for the year 2016-17 is at 36.01 Million Metric Tonnes (MMT) as against

production of 36.94 MMT in 2015-16, showing a decrease of about 2.53%. Whereas Natural Gas

production during the year 2016-17 is at 31.90 Billion Cubic Meters (BCM) which is 1.09% lower than

production of 32.25 BCM in 2015-16. The demand for petroleum has recorded a considerable

increase over the last few years due to the development activities in the country in the last few

years.

During the year 2016-17, the consumption of petroleum products in India was 194.60 MMT with a

growth of 5.37% as compared to consumption of 184.67 MMT during 2015-16. The consumption of

petroleum products during April-November, 2017 was at 134.60 MMT i.e. an increase of 3.40% over

130.17 MMT in April-November, 2016

Therefore, India is largely dependent on import of petroleum goods to meet its requirements.

Vedanta’s proposed exploratory drilling project could possibly result in the discovery of hydrocarbon

and in that case, would help in reducing India’s dependence on imports.

2.4.2Imports

Import of crude oil during 2016-17 was 213.93 MMT valued at 470159 crore as against import of

202.85 MMT valued at 416579 crore in 2015-16 which marked an increase of 5.46% in quantity

terms and 12.86% in value terms as compared to the import of crude oil during 2015-16. Import of

Crude Oil during April-November, 2017 was 144.72 MMT valued at 3,42,673 crore which marked an

increase of 9.31% in quantity terms and 15.32% in value terms as against the imports of 143.81 MMT

valued at 2,97,161 crore for the same period of last year.

2.5 Import versus indigenous production and export

India imports more than 80% of the petroleum products of its daily requirement.

2.6 Domestic Markets

The produced oil & gas, in case of commercially viable discoveries of hydrocarbons, will be utilized

for domestic purpose to supply the increasing demand in domestic market.

2.7 Employment generation

The seismic surveys are expected to take about 6 to 8 months to complete and will require a crew of

approximately 300 to 500 persons. And most of the workforce will be from local area. During the site

preparation for drilling, approximately 30-35 workmen will be employed per drill site. During the

drilling phase, about 50 workmen per shift will be working on site. This will include technical experts,

who will be responsible for various drilling related activities and some technical manpower engaged

are either from Vedanta Limited (Cairn Oil & Gas) or contractor’s crew as applicable. It is anticipated

that, at any given time, there will be about 80 - 100 personnel working on site including technical

10

staff, drilling crew, security staff etc. In case of commercial discovery of oil and gas additional

manpower will be employed for building of quick production facilities and associated activities.

3 Project Description

3.1 Type of project

The proposed project is a green field project. There is no interlinked and inter-dependent project.

3.2 Location with co-ordinates

The block CB-ONHP-2017/10 is located in BanaskanthaDistrict of Gujarat and Jalore district of

Rajasthan. It encloses an area of 2766Sq. Km. (coordinates given in Table -1) out of which 2100

sq.km. in Banaskantha District of Gujarat and is bounded by the points having following coordinates

Table-2 and 666 sqkm in Jalore District of Rajasthan, which coordinates given in Table-3. A map of

the contract area is shown in Figure 1.a & 1.b.

Figure-1.a: Location map of block CB-ONHP-2017/10 with state and district boundary

11

Table-1: Co-ordinates of Block CB-ONHP-2017/10 boundary (as per RSC)

Points Longitude Latitude

1 71° 50' 24° 40'

2 72° 0' 24° 40'

3 72° 0' 24° 10'

4 71° 50' 24° 10'

5 71° 50' 24° 16'

6 71° 49' 24° 16'

7 71° 49' 24° 17'

8 71° 47' 24° 17'

9 71° 47' 24° 16'

10 71° 39' 24° 16'

11 71° 39' 24° 18'

12 71° 38' 24° 18'

13 71° 38' 24° 19'

14 71° 37' 24° 19'

15 71° 37' 24° 21'

16 71° 36' 24° 21'

17 71° 36' 24° 22'

18 71° 35' 24° 22'

19 71° 35' 24° 31'

20 71° 30' 24° 31'

21 71° 30' 24° 50'

22 71° 50' 24° 50'

12

Figure-1.b: Location map of block CB-ONHP-2017/10 with state and district boundary

Table-2: Co-ordinates of Block CB-ONHP-2017/10 boundary in Banaskantha District of Gujarat (as

per RSC)

Points Longitude Latitude

S1 71° 30' 24° 40' 50.78

S2 71° 51' 28.08” 24° 40'

S3 71° 55' 12.83” 24° 40'

S4 71° 59' 7.14” 24° 40'

2 72° 0' 24° 40'

3 72° 0' 24° 10'

4 71° 50' 24° 10'

5 71° 50' 24° 16'

6 71° 49' 24° 16'

7 71° 49' 24° 17'

8 71° 47' 24° 17'

9 71° 47' 24° 16'

10 71° 39' 24° 16'

11 71° 39' 24° 18'

12 71° 38' 24° 18'

13 71° 38' 24° 19'

14 71° 37' 24° 19'

15 71° 37' 24° 21'

13

Points Longitude Latitude

16 71° 36' 24° 21'

17 71° 36' 24° 22'

18 71° 35' 24° 22'

19 71° 35' 24° 31'

20 71° 30' 24° 31'

Table-3: Co-ordinates of Block CB-ONHP-2017/10 boundary in Jalore district of Rajasthan (as per

RSC)

Points Longitude Latitude

S1 71° 30' 24° 40' 50.78

S2 71° 51' 28.08” 24° 40'

1 71° 50' 24° 40'

22 71° 50' 24° 50'

21 71° 30' 24° 50'

S3 71° 55' 12.83” 24° 40'

S4 71° 59' 7.14” 24° 40'

The block area covers total of 2766 Sq. Km and falls under Banaskantha District of Gujarat andJalore

District of Rajasthan.

3.3 Details of alternate site considered and the basis of selecting the proposed site

The block is allocated by the Government of India under the Revenue Sharing Contract (RSC).

Vedanta Ltd. - Cairn Oil & Gas is the Operator for this block. Drilling locations are proposed based on

geo-scientific information and alternate sites cannot be considered for the proposed project facilities

due to the following reasons:

The location is within the existing RSC boundary of the field/block. The locations of wells are

selected considering the drilling configuration (reach to reservoirs).

3.4 Size/ magnitude of operation

Theproposed onshore oil and gas exploration and appraisal and early production is expected to carry

out:

1. Seismic data acquisition

2. Drilling of 70 exploratory (including appraisal wells) and testing

3. Setting up of Early Production Units (UPUs)/ Quick Production Units (QPUs) for produced well

fluid processing and production of up to 28000 Bopd of crude oil and up to 4.2 MMSCFD of

associated natural gas.

4. The exploratory and appraisal wells will be drilled to explore the reservoirs up to a maximum

depth of 3500 m.

3.5 Project description with process details

3.5.1 2D & 3D Seismic survey:

Seismic surveys are a primary tool utilized during the exploration of hydrocarbons over land and

water. Seismic surveys are acquired by laying out energy source points (vibroseis or dynamite

charges) and receiver points (geophones) in a grid over the area to be surveyed.

14

The seismic data acquisition exercise (Recording) will take approximately 6 to 8 months. It should be

noted that while there are pre-determined seismic line transects based on analysis of pre-existing

data, the actual locations of the seismic transects may be varied prior to and/or during the seismic

data acquisition exercise. The seismic survey operation will be constrained along the seismic survey

lines and to the base and fly camps, as well as to the access roads to these areas.

Seismic 'upholes' are drill holes (20–50m in depth) placed at regular intervals (1–2km) along

exploration seismic lines. Seismic upholes will be drilled at regular intervals along the seismic lines.

The upholes will be drilled by a small truck-mounted rig usually using compressed air to lift soil

cuttings, adding water occasionally to lift gravelly material. Uphole drilling will take place during the

seismic survey. Uphole drilling is a relatively simple process and no drill casing is used. The drilling

fluids used in Uphole drilling consist of soil, ground sandstone and locally sourced water as a wet

mix. Apart from soil, ground sandstone and water, no chemicals will be added to the drilling fluid

only small quantities of bentonite clay if required during backfilling to seal off any encountered

groundwater. Once recordings have been made, the majority of the cuttings will be returned to the

hole. The cuttings present no risk to the environment in toxicity terms. Excess cuttings at each

Uphole, if any, are placed on top of the Uphole and will integrate into the soil over time.

3.5.2 Drilling of Exploration and Appraisal Wells

Vedanta Ltd. (Cairn Oil & Gas) proposes to drill 70 exploration & appraisal wells within the present

block boundary of CB-ONHP-2017/10.

The basic objectives of the exploratory drilling will be as follows:-

To determine the presence of potential hydrocarbon

To appraise discovered oil & gas

The lifecycle of drilling activities involve well site selection, site and access road preparation and its

maintenance, construction of drilling well, drilling activities, well testing and decommissioning and

closure of wells, if not proved economically viable for production of oil and gas.

If a discovery is made it is likely to need to be appraised. This is an intermediate step between

exploration and development which is necessary to confirm the reserve size and field deliverability

to an acceptable degree of accuracy. This may be in order to determine whether the discovery is

commercial, or to establish the parameters necessary to define the optimal development scheme for

the field. Appraisal may consist of additional seismic, further drilling or extended testing of an

existing well. Any or all of these types of operations may be deemed desirable or necessary.

To support the drilling operation, the following systems and services will be included at the rig

package:

Portable Living Quarters – to house essential personnel on site on a 24 hr basis.

These units are provided with Bath/Washroom.

Crane-age - cranes for loading/off-loading equipment and supplies.

Emergency Systems - it includes fire detection and protection equipment.

Environmental Protection – Blow out Prevention (BOP) system, wastewater treatment

unit, cuttings handling equipment.

15

Additionally, there will be other ancillary facilities like Drilling mud system, ETP, Cuttings disposal,

Drill Cementing equipment etc. and utilities to supply Power (DG sets), water, fuel (HSD) to the

drilling process and will be set up as a part of the project. The following flow chart of Figure 2 and

Figure 3shows the various phases of the drilling activities and model of drilling process respectively:

Figure 2: Various phases of the drilling activities

Figure 3: A typical model onshore drilling process

16

Location & Description of Drilling Wells

The exact locations for the drilling of exploratory and appraisal wells will be fixed once the detailed

interpretation of the acquired seismic survey is over. However, the wells will be strictly confined

within the acquired block itself. The specific details of the proposed wells are given in Table 4.

The proposed wells are located as shown in the Figure 4 and Figure 5 and tabulated in Table 3.3.

There is a wide variation in the Target Depths of the planned wells as the well depths vary from

1750m to 5000m due to the subsurface structural configuration and the depth of occurrence of the

primary reservoirs. Typically estimated drilling duration is 60-90 days/ well. In general, exploratory

and appraisal well testing duration is about 30 days/well. However, depending on the need, based

on nature of the reservoirs, the exploratory and appraisal wells will be tested for longer durations to

ascertain the reservoir parameters. Water Base Mud (WBM) will be used as drilling fluid for initial,

shallower sections where massive shale not encountered. The deeper and difficult to drill geological

formations will be drilled using Synthetic Base Mud (SBM) as drilling fluid.

Figure-4. Google map with Tentative Location of proposed wells on satellite map

17

Figure-5:Toposheet map with Tentative Location of proposed wells on satellite map

18

Table 4: Tentative well co-ordinates to be drilled in block CB-ON-HP-2017/10

Well id Longitude Latitude

1 71° 53' 25.979" E 24° 11' 59.463" N

2 71° 56' 58.336" E 24° 12' 3.753" N

3 71° 53' 21.250" E 24° 15' 14.267" N

4 71° 56' 53.696" E 24° 15' 18.568" N

5 71° 42' 38.986" E 24° 18' 15.638" N

6 71° 46' 11.479" E 24° 18' 20.197" N

7 71° 49' 43.986" E 24° 18' 24.674" N

8 71° 53' 16.508" E 24° 18' 29.069" N

9 71° 56' 49.043" E 24° 18' 33.381" N

10 71° 39' 1.391" E 24° 21' 25.752" N

11 71° 42' 33.959" E 24° 21' 30.405" N

12 71° 46' 6.542" E 24° 21' 34.976" N

13 71° 49' 39.140" E 24° 21' 39.464" N

14 71° 53' 11.751" E 24° 21' 43.869" N

15 71° 56' 44.377" E 24° 21' 48.193" N

16 71° 36' 17.467" E 24° 24' 30.373" N

17 71° 38' 56.260" E 24° 24' 40.505" N

18 71° 42' 28.918" E 24° 24' 45.170" N

19 71° 46' 1.591" E 24° 24' 49.752" N

20 71° 49' 34.279" E 24° 24' 54.252" N

21 71° 53' 6.981" E 24° 24' 58.668" N

22 71° 56' 39.696" E 24° 25' 3.002" N

23 71° 36' 12.231" E 24° 27' 45.113" N

24 71° 38' 51.114" E 24° 27' 55.257" N

25 71° 42' 23.862" E 24° 27' 59.934" N

26 71° 45' 56.626" E 24° 28' 4.527" N

27 71° 49' 29.404" E 24° 28' 9.038" N

28 71° 53' 2.196" E 24° 28' 13.466" N

29 71° 56' 35.002" E 24° 28' 17.811" N

30 71° 36' 6.979" E 24° 30' 59.851" N

31 71° 38' 45.952" E 24° 31' 10.007" N

32 71° 42' 18.791" E 24° 31' 14.696" N

33 71° 45' 51.646" E 24° 31' 19.301" N

34 71° 49' 24.514" E 24° 31' 23.823" N

35 71° 52' 57.397" E 24° 31' 28.261" N

36 71° 56' 30.294" E 24° 31' 32.617" N

37 71° 31' 34.961" E 24° 34' 15.106" N

38 71° 35' 7.861" E 24° 34' 19.973" N

39 71° 38' 40.776" E 24° 34' 24.756" N

40 71° 42' 13.706" E 24° 34' 29.456" N

41 71° 45' 46.651" E 24° 34' 34.072" N

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Well id Longitude Latitude

42 71° 49' 19.611" E 24° 34' 38.606" N

43 71° 52' 52.585" E 24° 34' 43.056" N

44 71° 56' 25.573" E 24° 34' 47.422" N

45 71° 31' 29.587" E 24° 37' 29.829" N

46 71° 35' 2.578" E 24° 37' 34.708" N

47 71° 38' 35.584" E 24° 37' 39.503" N

48 71° 42' 8.605" E 24° 37' 44.214" N

49 71° 45' 41.642" E 24° 37' 48.842" N

50 71° 49' 14.692" E 24° 37' 53.387" N

51 71° 52' 47.758" E 24° 37' 57.848" N

52 71° 56' 20.837" E 24° 38' 2.225" N

53 71° 31' 24.198" E 24° 40' 44.550" N

54 71° 34' 57.280" E 24° 40' 49.441" N

55 71° 38' 30.377" E 24° 40' 54.248" N

56 71° 42' 3.490" E 24° 40' 58.971" N

57 71° 45' 36.618" E 24° 41' 3.611" N

58 71° 49' 9.760" E 24° 41' 8.167" N

59 71° 31' 18.792" E 24° 43' 59.269" N

60 71° 34' 51.966" E 24° 44' 4.172" N

61 71° 38' 25.155" E 24° 44' 8.991" N

62 71° 41' 58.359" E 24° 44' 13.726" N

63 71° 45' 31.579" E 24° 44' 18.378" N

64 71° 49' 4.813" E 24° 44' 22.945" N

65 71° 31' 13.371" E 24° 47' 13.987" N

66 71° 34' 46.637" E 24° 47' 18.902" N

67 71° 38' 19.918" E 24° 47' 23.733" N

68 71° 41' 53.214" E 24° 47' 28.480" N

69 71° 45' 26.526" E 24° 47' 33.143" N

70 71° 48' 59.852" E 24° 47' 37.721" N

Note:- Actual geo-graphical surface coordinates of exploratory and appraisal well locations within

2000m radius of the proposed coordinates.

Site Selection

The exploration history of the area exhibits the potential presence of the oil and gas in the region.

The seismic data interpretation of the seismic survey would decide the exact locations of the drilling

well.The proposed exploratory well site will be identified based on the study and interpretation of

the stratigraphy and seismic data. Within the identified location the actual well drilling site will be

selected based on the following factors:

Located at least 200 m away from the nearest habitat / sensitive receptors

Located at a safe distance (at least the boom / mast length away) from public road

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Safe distances from any radio transmitters so that the use of explosives and detonators may

proceed without the danger of external activation

Ensure natural drainage channels are avoided or drainage channels rerouted to ensure

unhindered flow of rain / flood water. Where necessary adequate erosion control measures

will be provided

Land Requirement

An area of approximately 300m X 300m would be taken on temporary short-term lease basis for the

construction of well pad (drill site) for exploratory and appraisal wells. For the preparation of

suitable access roads connecting to well pads, accommodating OHL and other utilities in future, a

width of 30m (approx.) RoU will be required.

Site preparation will involve all activities required to facilitate the operation of the drilling rig and

associated equipment and machineries. At the initial stage, the drilling site will be elevated to about

2.0 m from the existing ground level with minimal clearance of existing ground vegetation. The loose

top soil will be removed by using mechanical means like bulldozer and saved at a nearby place for

later use during site restoration. Levelling and compaction will be done with the help of graders and

mechanical rollers. The land filling materials and rubbles will be required for the purpose of site preparation in sufficient

amount. All such materials will be procured by Vedanta (Cairn Oil & Gas) through contractors and it

will be ensured that they source the materials from government approved borrows and quarries. A

backhoe will be used for all excavation and cutting activities (for construction of pits) on site.

Subsequently, the proposed well site & campsite will be duly fenced using chain link and barbed

wires.

Drilling Rig

The proposed drilling shall be carried out by using a standard land rig or a “Mobile Land Rig” with

standard water based drilling fluid treatment system. This rig will be suitable for deep drilling up to

the desired depth of 6000 meters (TVDSS) as planned for the project. The typical configuration of a

Drilling Rig is shown in the Fig 3.6 and given in Table 3.4. Additionally, there will be other ancillary

facilities like Drilling mud system, ETP, Cuttings disposal, Drill Cementing equipment etc. and utilities

to supply power (DG sets), water, fuel (HSD) to the drilling process and will be set up as a part of the

Project.

Table 5Details of the drilling rig

Type of Rig Electrical Rig

Drilling mud composition Water based Drilling Fluid

Power generator type & nos. AC – SCR Type. (03 Nos.)

Details of solids handling

systems on rig

Shale Shakers - 1200 GPM Capacity Desander – 1200 GPM

Capacity Desilter – 1200 GPM Capacity

21

Figure-6: Typical configuration of a Drilling Rig

Drilling Activities

A rig will be installed at the potential site of drilling after thorough inspection for its working

capability and quality standards. Well spudding shall be the start of drilling activity. Wells will be

drilled in sections, with the diameter of each section decreasing with increasing depth. Before

commencing the actual drilling, large diameter pipe (Conductor) will be lowered into a hole and

cemented/grouted. Top-hole section will be drilled to a desired depth based on well design. After

drilling top-hole section, it will be cased with a pipe called “Casing”. Once each section of the well is

completed, the drill string is lifted and protective steel pipe or casing lowered into the well and

cemented into place. The lengths and diameters of each section of the well will be determined prior

to the starting of the drilling activities and are dependent on the geological conditions through which

the well is to be drilled. This process of drilling and casing the hole section continues until the final

well depth (target) is achieved. Drilling process is associated with various hazards such as well active

situation (kicks), blowouts, H2S situation etc.

Mud System and Cuttings

During drilling operations, the drilling fluid (or mud) is pumped through the drill string down to the

drilling bit and returns at the drill pipe–casing annulus up to surface back into the circulation system

after separation of drill cuttings /solids through solids control equipment. The primary function of

drilling fluid is to ensure that the rock cuttings generated by the drill bit are continuously removed

from the wellbore. The mud must be designed such that it can carry the cuttings to surface while

circulating, suspend the cuttings while not circulating and drop the cuttings out of suspension at the

surface. The drilled solids are removed at the surface by mechanical devices such as shale shakers,

de-sanders and de-silters. The hydrostatic pressure exerted by the mud column prevents influx of

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formation fluids into the wellbore. The instability caused by the pressure differential between the

borehole and the pore pressure can be overcome by increasing the mud weight. Hydration of the

clays can be overcome by using non aqueous based muds, or partially addressed by treating the

mud with chemicals which will reduce the ability of the water in the mud to hydrate the clays in the

formation. Water based mud will be used for initial, shallower sections where massive shales are

not encountered. The deeper and difficult to drill formations will be drilled using synthetic base

mud (SBM). Synthetic base mud unlike oil based mud (OBM) is biodegradable but can be re-used. At

the end of drilling a well almost the entire amount of the SBM is collected for re-use in next drilling

operation. SBM systems promote good hole cleaning and cuttings suspension properties. They also

suppress gas hydrate formation and exhibit improved conditions for well bore stability compared to

most WBM. WBM typically consists of water, bentonite, polymers and barite. Other chemical

additives viz. glycols and salts may be used in conjunction to mitigate potential problems related to

hydrate formation. The mud to be used will be continuously tested for its density, viscosity, yield

point, water loss, pH value etc. The mud will be prepared onsite (drill location) using centrifugal

pumps, hoppers and treatment tanks.

During drilling activity, cuttings will be generated due to crushing action of the drill bit. These

cuttings will be removed by pumping drilling fluid into the well via triplex mud pumps. The mud

used during such operation will flush out formation cuttings from the well hole. Cuttings will be

then separated from drilling mud using solids-control equipment. This will comprise a stepped

system of processes consisting of linear motion vibrating screens called shale shakers, hydro-

cyclones (including de-sanders and de-silters), and centrifuges to mechanically separate cuttings

from the mud.

Figure-7: Flow Chart for Drilling Mud & Solid Discharge

Cementing Programme

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Cementing is a necessary aspect of exploratory and appraisal drilling oil and gas wells. Cement is

used to fulfill the following works:

Secure/support casing strings

Isolate zones for production purposes

Cementing generally utilizes Portland cement (API Class G Oil Well Cement) with various additives in

small quantities as accelerators/retarders, density adjusters, dispersants, fluid loss additives, anti gas

migration additives etc.

Well Evaluation

During the drilling operations for different zones, logging operations will be undertaken to get

information on the potential type and quantities of hydrocarbons present in the target formations.

Technicians employed by a specialist logging Service Company do well logging by different well

logging techniques including electric, sonic and radioactive techniques. Logging instruments

(sensors) are attached to the bottom of a wire line and lowered to the bottom of the well and they

are then slowly brought back. No emissions to the environment or any environmental harm is

associated with wire line logging operations. The radioactive source required for well logging

operations are kept in specially designed container.

A drill-stem test is frequently performed to evaluate the formation or zone from which the gas show

was observed. A drill-stem test enables the exploration company to obtain a sample of the fluids

and gases contained in the formation or interval being tested as well as pressure information, which

is determined by special gauges within the test tool. The test tool contains a valve which may be

opened and closed to allow formation fluids to enter the test tool and drill string. If there is

sufficient fluid and pressure within the zone being tested, the formation fluid may rise to the

surface and flow into special test tanks used for that purpose. If gas is present, it is burned at the

surface as a flare.

Hydraulic Fracturing – for Tight Rock Reservoirs of Hydrocarbons

Hydraulic fracturing is used in tight rock reservoirs with low permeability, such as shale (i.e., the

conductivity or ability of hydrocarbons to flow in the formation is low because of the small pore size

in the rock). The goal of hydraulic fracturing in tight reservoir (shale) formations is to enable a well to

produce the resource or to increase the rate at which a well is able to produce the resource.

Hydraulic fracturing may be conducted in wells with low permeability formation and low pressure.

Wells requiring hydraulic fracturing and numbers of stages of hydraulic fracturing per well will

depend on seismic data acquired & interpreted and data acquired during the drilling phase of the

project.

Hydraulic fracturing is a common technique used to stimulate the production of oil and natural gas

by creating fractures or cracks that extend from the well hole into the rock formations. This is

accomplished by injecting fluid, which is usually a mixture of water and high viscosity fluid additives,

under extremely high pressure. The pressure of the water will then exceed the strength of the rock,

causing fractures to enlarge. After the fractures take place, a “propping agent” known as proppant

(which is usually sand) is injected into the fractures to keep them from closing. This allows the

hydrocarbon to move more efficiently from the rock to the well. A single well may require up to

15,000 m3 of water which may vary depending on the fracking requirements. For the hydraulic

fracturing in a well, proppant mass of 150,000 – 200,000 lbs per stage and fluid volume of 2500 bbls

– 4000 bbls per stage will be required.

24

Fracturing effluent generated will be discharged in the HDPE lined pits at the drilling well sites.

Additional land will be procured wherever required. For effective recycling and reuse of the frac

fluid, effluent treatment plant (ETP) will be installed, thus raw water required for fracturing will be

minimized.

Completion of Drilling

On completion of activities, the well will be either plugged and suspended (if the well evaluations

indicate commercial quantities of hydrocarbons) or will be killed and permanently abandoned. In

the event of a decision to suspend the well, it will be filled with a brine solution containing very

small quantities of inhibitors to protect the well. The well will be sealed with cement plugs and

some of the wellhead equipment (Blind Flange) will be left on the surface (Cellar). If the well is

abandoned it will be sealed with a series of cement plugs, all the wellhead equipment will be

removed, by leaving the surface clear of any debris and the site will be restored.

Decommissioning & closure of wells

After the completion of the drilling activity, partial de-mobilization of the drilling rig and associated

infrastructure will be initiated. As discussed earlier, well testing may be carried out immediately

after the drilling is completed. The complete de-mobilization of the facilities at site will happen once

well-testing completed successfully. This will involve the dismantling of the rig, all associated

equipment and the residential camp, and transporting it out of the project area. It is expected that

demobilization will take approximately 20-25 days and will involve the trucking away of materials,

equipment and other materials from the site to bring it back to its original condition. It is estimated

that about 50 truckloads will be transported out of site during this period. If no indication of any

commercially viable amount of oil or gas is encountered either before or after testing, the well will

be declared dry and accordingly will be plugged of and abandoned, and the site will be restored in

line with regulations and good industry practice.

Appraisal

When, exploratory drilling is successful, more wells (termed as Appraisal wells) will be drilled to

determine the size and the extent of the field. Wells drilled to quantify the hydrocarbon reserves

found are called as ‘appraisal’ wells. The appraisal activity will be carried out with an aim to

evaluate the size and nature of the reservoir, to determine the number of confirming or appraisal

wells required, and whether any further seismic survey is necessary. The technical procedures and

activities in appraisal drilling will be the same as those employed for exploration wells. A number of

wells may be drilled from a single well pad/ drill site. Deviated or directional drilling at an angle

from a site adjacent to the original discovery well may be used to appraise other parts of the

reservoir, in order to reduce the land requirement.

Setting up of Early Production Units (EPUs)/ Quick Production Units (QPUs) and early Production

Vedanta Ltd (Cairn Oil & Gas), as an interim plan, in case of commercially viable discovery (s) of

hydrocarbons in the block and having established the size of the hydrocarbon field (s), proposes to

immediately bring the field (s) into production using one or more of the appraisal wells for the

25

production of crude oil by setting up of Early Production Units (EPUs) or QPUs (Quick Production

Units). Early production of the Crude oil will enable the Country to reduce dependence on import of

crude oil.

Here, it may be noted that after the commercially viable discovery (s) of the hydrocarbon field(s),

following the typical life cycle of Oil & Gas Exploration & Production sector, full-fledged field

development plan including development well drilling, establishing crude oil & natural gas

processing facilities, laying of intra-field & cross country pipelines and other associated physical and

social infrastructures will be taken up and prior development EC and other approval will be obtained

as applicable. The lead time for entire process is about 3 – 4 years for the production of crude oil and

natural gas.

Once the full-fledged field development comes up, the Early Production Unit(s)/ Quick Production

Unit(s) will suitably be integrated with the full-fledged facilities and/ or phased out.

Early Production Units (EPUs) or QPUs (Quick Production Units) will be installed for the processing of

produced well fluid. A EPU/ QPU will be a packaged/ modular mobile unit and will mainly consists of

a three phase separator & production heater or heater-treater, oil storage tanks, oil tanker loading

system, produced water (PW) separation and disposal system, power generation (GEG or DG), utility

systems such as fuel gas, flare & Inst. Air packages, firefighting equipment, etc. Each EPU/ QPU

capacity will be ~2,000 BFPD (Barrels of Fluid per Day).

The EPUs/ QPUs will be installed near the already established exploration and appraisal well location

within the well pad in the commercially viable discovered oil field. The separated crude oil will be

stabilized further, stored in storage tanks and subsequently send through road tankers to the

nearing available facilities like terminals/ depots. The produced gas will be used for internal heating,

power generation purpose as far as possible & surplus gas will be safely disposed off using flare

system.

The produced water will be treated to achieve MoEF/ CPCB/ SPCB specification (discharge standards)

and will be disposed off. The treated effluent (produced water) will be disposed off using either a

nearby down hole disposal well (by reinjection in abandoned well) or other available & suitable

onshore disposal medium or solar/ mechanical evaporators depending on the quantity.

The power requirement will be met through state electricity grid and/ or installation of Diesel/ Gas

Engine Generator(s) using produced gas.

The water requirement for the oil and gas processing will be sourced locally through approved

authorities or through extraction of ground water. In case of extraction of ground water, permission

(NOC) will be obtained from CGWA/ CGWB (Central Ground Water Authority/ Board) of from State

Govt. Installation of raw water treatment plant will be done depending on the need for process

water and domestic water consumption.

The typical broad requirements envisaged for the well fluid processing and production of crude oil

and associated natural gas through QPF are the following:

Wells with selected artificial lift; & flow lines;

Combination of Heater (using produced gas) & 3 phase separator or single heater-treater

26

Stabilized Crude oil storage, pumping & tanker loading facilities;

PW separation and disposal system;

Fuel gas system, Instrument air/ gas system;

Flare system, Firefighting equipment, Raw water treatment plant;

Diesel/ Gas Engine Generator (s);

Domestic sewage treatment facility (STP or septic tank & soak pit system);

3.6 Raw materials required and source

Broad requirements of raw materials:

Seismic Acquisition

The seismic survey will be conducted using dynamite charges. The explosive sources (dynamites) and

drilling fluid chemicals for shot hole drilling will be procured by the company before commencement

of the operations. During surveying the main tasks include initial installation of a small number of

survey control points, then setting-out source points and receiver stations for use. This would be

done by the conventional survey method of using RTK GPS backpack surveying units and

biodegradable markers. Cutting activities though minimal for the receiver and source lines shall be

done manually or mechanically where appropriate. In open areas where there is clear line of sight no

cutting shall be done. Recording involves laying of geophones on the receiver stations and

generating energy (vibrations) on the perpendicular source lines to generate seismic energy, which

are reflected and recorded on magnetic tapes via the recording instrument.

Drilling

During drilling activities, materials like HSD, Steel (in the form of casings & tubulars) and chemicals

like barite, oil well cement and bentonite will be required. Other production equipments like tubular

(Casing and tubings), wellhead assembly, packer etc, and chemicals for mud and cementing required

for the drilling operations and shall be procured by the company from within the country and from

abroad before the commencement of operations.

Water based mud will be used for initial, shallower sections where massive shales are not

encountered. The deeper and difficult to drill formations will be drilled using synthetic base mud

(SBM). Synthetic base mud unlike oil based mud (OBM) is biodegradable but can be re-used. WBM

typically consists of water, bentonite, polymers and barite. Other chemical additives viz. glycols and

salts may be used in conjunction to mitigate potential problems related to hydrate formation.

Requirement WBM (approx.) 800-1000 m3/well

Requirement SBM (approx.) 600-800 m3/well

3.7 Resource optimization / Recycling and Reuse envisaged in the project

Maximum care will be taken for resource optimization, wherever possible with an aim of

Resource Conservation

Elimination of Waste Streams

Minimizing Waste

Reuse/recycle of Wastes

27

The drill cuttings from the drilling operations associated with water based mud will be used

for filling low lying areas as a sub grade construction material in construction of well pads

and surface facilities.

Synthetic base mud will be re-used in further drilling activities.

3.8 Availability of Water and Energy/Power

3.8.1 Water Requirement

Seismic Operations:

The water required during seismic operation will be mostly for domestic use which is about 20-30

m3/day.

Drilling Operations

Wells will be drilled by using either water-based mud or synthetic oil based mud. The water

requirement in drilling rig is mainly meant for preparation of drilling mud apart from washings and

domestic use. The water requirement for all the project activities will be sourced locally through

approved/ authorized sources of surface water and/ or ground water (e.g. PHD bore wells, privately

owned bore wells, Irrigation Dept./ Water Resources Dept. of State Govt.). In case, required water

could not be sourced from locally available approved sources, ground water will be extracted after

obtaining permission from CGWA/ State Govt. The water requirement per well is shown in Table 3.5.

Water requirement

Description Quantity

Water for domestic use 20-30 m3/well/day

Drilling water consumption for mud preparation 600-1000 m3/well (WBM)

and 150-300 m3/well (SBM)

Water requirement for miscellaneous use (Engine cooling,

floor/equipment/string wasteline, firefighting, storage/makeup)

during drilling phase (KL)

25-50 m3/well/day

The water requirement for all the project activities will be sourced locally through approved/

authorized sources of surface water and/ or ground water (e.g. PHD bore wells, privately owned

bore wells, Irrigation Dept./ Water Resources Dept. of State Govt.). In case, required water could not

be sourced from locally available approved sources, ground water will be extracted after obtaining

permission from CGWA/ State Govt.

3.8.2 Power Requirement

Seismic Operations

The power requirement during seismic is 350 KVA will be provided through diesel generator (DG)

sets or state grid.

During Drilling Operations

The power requirement in the drilling site and the campsites will be provided through diesel

generator (DG) sets. The rated capacity of the DG sets required for onshore drilling site is provided in

following table.

Table 7: Details of DG sets of Onshore Drilling Activity

Location DG Capacity

Camp site 2 X 350 kVA (one working and one standby)

Drilling site 3 x 1000 kVA ( two working and one standby)

28

Radio Room 2X100 kVA

3.9 Quantity of waste to be generated and its disposal

3.9.1 Waste water generation

The drilling operation would generate wastewater in the form of wash water due to washing of

equipment, string and cuttings etc. The only other source of wastewater generated from drilling

operation is sewage from sanitation facilities, around 15-25 m3/day/well, which shall be disposed

through septic tanks/soak pits. It is expected that wastewater in the form of Drill cutting washing +

Rig washing+ cooling etc shall be generated at an average rate of around 30-40 m3/day during the

drilling operations from a single well. Waste water will be discharged in HDPE lined evaporation pit

for disposal, size of the pit is generally 50mx20mx1.5m. The wash water would contain variable

quantities of mineral salts, solids, suspended and dissolved hydrocarbons, and other organic and

inorganic components in very minor quantities.

3.9.2 During Drilling Operations:

Waste water generation

The drilling operation would generate wastewater in the form of wash water due to washing of

equipment, string and cuttings etc. The only other source of wastewater generated from drilling

operation is sewage from sanitation facilities, around 15 - 25 m3/day/well, which shall be disposed

through septic tanks/soak pits. It is expected that wastewater in the form of Drill cutting washing +

Rig washing+ cooling etc shall be generated at an average rate of around 30-40 m3/day/well during

the drilling operations from a single well. Waste water will be discharged in HDPE lined evaporation

pit for disposal, size of the pit is generally 50mx20mx1.5m. The wash water would contain variable

quantities of mineral salts, solids, suspended and dissolved hydrocarbons, and other organic and

inorganic components in very minor quantities.

Waste Management

The drill cuttings and spent drilling mud will be generated at site per well during drilling operations.

This will be stored in well-designed HDPE line pit. It will be tested for its hazardous constituents (Oil

and Grease), If found to be hazardous, It will be handed over to authorized TSDF. In case of

Nonhazardous, it will be disposed insitu in HDPE lined pit.

Used /waste Oil – During the drilling approx. 1-2 tons/well of spent oil will be generated per well.

This oil will be sent to authorized recyclers.

Domestic waste of 25-30 kg/day per well will be generated at site, which will be segregated at

source (Organic / Inorganic) and disposed accordingly.

Disposal of wastes will be as per prior approval of SPCB.

Table 8: The expected waste generation from well drilling

S.No. Nature of waste Quantity during Drilling Activities

A Hazardous Waste

1. Drill cuttings associated with WBM

Drill cuttings associated with SBM

250-750 tons/well m3 per well

500-1500 tons/well

2. Spent /Residual drilling mud 250-500 tons/well

3. Used Lubricating oil, 1-2 tons/well

29

Sludge containing oil and other drilling work 250-500 tons/well

B Non Hazardous Waste

4. Food waste 25-30 Kg per well

5. Non-combustible waste containing metallic

residues, glass 1000-1200 Kg/well

6. Packaging wastes including drums, wooden pallets,

plastic containers, plastic foils. 1000 kg/well

7.

Left over chemicals and materials, scrap metal,

sludges, scales, batteries, spent acids, spent

lubricants, filters etc.

250-300 kg/well

8. Cement, grit, blasting and painting wastes. 500 kg per well

3.10 Schematic of feasibility drawing The well site will be sized to contain all equipment and buildings, storage, workshops, etc. using

distances between various rig components in line with existing rules and regulations for the area of

operation and the approved standard operating procedures of the drilling contractor. The land

requirement for the well drill site would therefore vary from approximately 300m X 300m size

maximum. The typical layout of the well site is as below:

Figure 8: Schematic for a typical Well Pad

Each exploratory well drill site will require the following:

Potable office cabins / rest rooms (container type cubicles);

Drilling rig foundation and cellar;

Foundation / Pits for equipment;

Space for drill rig equipment, working area and materials lay down area;

Waste storage pits;

Cutting disposal (impervious lined) pits;

30

Solar evaporation pits (waste drilling fluid disposal);

Water storage pit;

Septic tank with soak pits;

Paved and contained chemical storage area;

Above ground Diesel storage tanks with paved and bunded area;

Below ground level flare pit (well testing);

Provisional space for definitive fracking program.

Radio room;

Storm water drainage system;

Internal roads and fencing.

The drill site is restricted access area and is fenced all round with round the clock watch. Entry of

vehicles into the drilling site area is prohibited except for material movement. Adequate parking are

provided outside the drilling location.

4. Site Analysis

4.1 Connectivity

The project location is situated in in Banaskantha District of Gujarat &Jalore District of Rajasthan. Tharad Town, Gujarat is located within the block and Patan, Gujarat is about 38Km, South from the block.The project location is well connected by road, rail and by Air. NH-15, NH-68, SH-54, SH-128 and SH-129 passes through the block.Bhildi Railway Station is 900m, East from the block, Dhanera Railway Station is

3.2Km, East from the block and Diyodar Railway Station is 8.8Km, South from the block)

4.2 Land form, land use and land ownership

Sanchore town and Tharad town falls within the block.Luni River is flowing within the block from west to

east on North side of the Block boundary. Banas River is Flowing at 5.3Km, South from the block boundary

4.3 Topography (along with map)

The block area is almost flat topography with elevation varying approximately 22m to 128m across area. The terrain of the Banaskantha district, Gujarat is flat level plain with an altitude ranging from 49 m to 128 m above MSL. The slope gradient of this district is from North to South. The south eastpart of the district is relatively higher and attains the maximum altitude of 128 m above MSL and the elevation gradually decreases towards North. The terrain of the Jalore district, Rajasthan is flat level plain with an altitude ranging from 19 m to 122 m above MSL. The slope gradient of this district is from NorthwesttoNorth east. The NE part of the district is relatively higher and attains the maximum altitude of 122 m above MSL and the elevation gradually decreases towards NW. Figure 5tab below shows the Topographic map of the study area. Topography sheet is given in Fig. 4 of this document.

4.4 Existing land use pattern and relative location of protected areas

The entire block area is divided into following land use types

Agriculture land

Land with scrubs

Land without scrubs

Habitation

Water bodies

4.5 Existing infrastructure/ industries

The block area is located in Banaskantha districts, Gujarat and Jalore district, Rajasthan, well

equipped with existing infrastructure like roads, rail lines, water supply, power supply, sewerage

facility, telecommunication facilities, hospitals, schools etc.

31

4.6 Soil Classification

In Banaskantha district major part of the soils are sandy in nature. In general the soils are poor to

medium in fertility and water retention capacity. Most soils have good aeration, porosity and

permeability. JaloreDistirctSoils are shallow with deep gravel encrusted with CaCO3. The texture of

the soils in general varies from sandy to sandy loam but in deltaic areas of the Luni River south to

southwest of Sanchore, the soils are loamy alluvium.

4.7 Climatedata from secondary sources

The climatological summary details of parameters like temperature, relative humidity, rainfall, cloud

cover, wind speed and wind direction monitored at IMD Deesa is given below:

Table 9: Climatological Summary at IMD Deesa (1961 – 1990)

Month

Daily mean Temp. (0C)

Relative Humidity

(%) Rainfall (mm)

Cloud cover (in

Okta)

Mea

n W

ind

Sp

eed

(k

m/h

) Predominant Wind

Direction

Calm (%)

Max

Min

8:3

0

17

:30

Mo

nth

ly

Tota

l

No

. of

Rai

ny

day

s

8:3

0

17

:30

8:3

0

17

:30

January 26.8 10.1 67 36 2.6 0.3 1.1 1.1 6.0 SE 40 37

February 29.2 12.1 61 30 1.8 0.2 1.3 1.4 6.2 E 43 31

March 34.6 17.2 53 25 0.5 0.1 1.4 1.6 6.1 E 48 23

April 38.7 22.0 55 23 0.5 0.1 1.2 1.4 6.7 E 45 18

May 40.3 25.2 67 26 4.3 0.5 2.0 0.9 8.8 NE 27 11

June 38.6 26.9 74 40 72.2 2.7 4.4 3.2 10.8 NE 15 12

July 33.7 25.6 83 62 229.0 8.6 6.4 6.2 9.2 NE 23 15

August 32.2 24.7 86 67 195.3 7.8 6.3 6.3 7.4 NE 30 23

September 34.4 24.0 79 52 75.4 3.4 3.6 4.0 6.0 NE 43 29

October 36.1 20.6 64 35 15.7 1.0 1.2 1.6 4.8 E,SE,NE 54 48

November 32.7 15.7 60 35 4.0 0.5 1.0 1.2 4.8 SE 52 61

December 28.7 11.6 66 37 1.1 0.2 1.2 1.3 5.3 SE 44 51

Annual or Mean

33.8 19.6 68 39 602.3 25.5 2.6 2.5 6.8 NE 38 31

Source: India Meteorological Department (IMD)

The climatological summary details of parameters like temperature, relative humidity, rainfall, cloud

cover, wind speed and wind direction monitored at IMD Barmer is given below:

Table 10 : Climatological Summary at IMD Barmer (1961 – 1990)

Month

Daily mean Temp. (0C)

Relative Humidity

(%) Rainfall (mm)

Cloud cover (in Oktas)

Mea

n W

ind

Sp

eed

(k

m/h

) Predominant Wind Direction

Calm (%)

Max

Min

8:3

0

17

:30

Mo

nth

ly

Tota

l

No

. of

Rai

ny

day

s

8:3

0

17

:30

8:3

0

17

:30

January 25.6 10.4 54 30 1.2 0.2 1.8 1.9 4.3 NE 39 28

February 28.4 12.9 51 26 2.4 0.3 1.9 2.1 5.0 SW 40 22

March 34.1 18.7 47 22 0.9 0.1 2.2 2.7 6.1 E 39 21

April 39.1 24.1 45 21 4.1 0.7 1.6 2.4 7.9 NE 33 20

32

Month

Daily mean Temp. (0C)

Relative Humidity

(%) Rainfall (mm)

Cloud cover (in Oktas)

Mea

n W

ind

Sp

eed

(k

m/h

) Predominant Wind Direction

Calm (%)

Max

Min

8:3

0

17

:30

Mo

nth

ly

Tota

l

No

. of

Rai

ny

day

s

8:3

0

17

:30

8:3

0

17

:30

May 41.7 26.6 56 23 11.4 0.8 1.1 1.5 9.9 NE 19 11

June 40.5 27.5 68 33 30.9 1.8 3.2 2.4 10.8 NE 9 9

July 36.7 26.5 77 49 88.0 4.3 5.6 5.1 9.4 NE 14 9

August 35.1 25.6 79 53 91.9 4.1 5.4 5.2 8.5 NE 15 11

September 36.3 24.7 73 42 34.6 1.8 2.7 3.3 7.14 NE 26 18

October 36.9 22.0 54 30 3.5 0.4 1.0 1.9 4.7 NE 46 43

November 32.3 16.3 50 30 1.4 0.2 0.9 1.2 3.3 SW 57 55

December 27.5 11.7 52 31 0.4 0.0 1.6 1.9 3.7 SW 47 45

Annual or Mean

34.6 20.7 59 32 270.6 14.8 2.4 2.6 6.8 NE 31 24

4.7.1 Wind

The monthly mean wind speed varied from 4.8 to 10.8km/hr occurring in October and June months

respectively. The calm winds at 8:30 hrs varied from 15% (June) to 54% (October) while at 17:30 hrs

varied from 11% (May) to 61% (November). The table reveals that Morning hour’s had higher calm

winds as compared to evening hours. The monthly mean wind speed has been recorded close to

6.8m/s..

The monthly mean wind speed varied from 3.3 to 10.8km/hr occurring in November and June

months respectively. The calm winds at 8:30 hrs varied from 9% (June) to 57% (November) while at

17:30 hrs varied from 9% (June) to 55% (November). The table reveals that Morning hour’s had

higher calm winds as compared to evening hours. The monthly mean wind speed has been recorded

close to 6.8m/s.

4.7.2 Storms andcyclones

The block area of Gujarat doesn’t fall under high risk zone with respect to cyclone and storms as per

Gujarat Cyclone Hazard Risk Zonation and the block area of Rajasthan falls under very high risk zone

with respect to cyclone and storms as per Rajasthan Cyclone Hazard Risk Zonation

4.7.3 Rainfall

The IMD data revealed that rainfall occurred at Deesa region is maximum in July (229.0 mm) and

Bramermaximum in July (88 mm). The total rainfall of Deesa received in year is about 602.3 mm and

the total rainfall of Barmer received in year is about 270.6 mm.

4.7.4 Temperature andHumidity

The monthly mean maximum temperature of Deesafor a period of 100 years varied from 26.8°C in

January to 40.34°C in May.The monthly mean maximum temperature of Barmerfor a period of 100

years varied from 25.6°C in January to 41.7°C in May.

33

5 Planning Brief

5.1 Planning concept

The project is a green field oil and gas exploration & appraisal and early production in CB-ONHP-

2017/10 Block of area 2766 km2out of which 2100sq.km.inBanaskanthaDistrict of Gujarat and 666

sq.km.inJaloreDistrict of Rajasthan.

Well sites and roads will be built or upgraded for transportation of rig and its equipment for seismic

acquisition and drilling. The drilling will be carried out following the international safety standards.

Upon successful exploration the well will be completed and suspended for further activities and the

wells devoid of hydrocarbon will be plugged and abandoned. The land will be restored back to its

original form.

5.2 Population projection

Direct and indirect employment will be created due to project. Temporary influx of people will be

there as the managerial and supervisory staff will generally be outsider.

5.3 Land use planning (break up along with green belt, etc)

The land within the block will not be taken completely for drilling of the wells. An area of about

300m X 300m would be taken on temporary short-term lease basis for the construction of well pad,

drill site, etc.

5.4 Assessment of Infrastructure demand

No major infrastructure (physical and social) is anticipated. The infrastructure demand will be very

less as the number of employee at drilling wells for a short duration. Temporary road will be taken

up by Vedanta (Cairn Oil & Gas) for the drilling well site for the movement of heavy equipment.

5.5 Amenities and facilities

The amenities/ facilities

Potable drinking water

Firefighting/ alarm system and ambulance is available in case of emergency

Drinking water, canteen and electricity facilities is provided

Separate sanitation facilities will be provided for men and women.

6. Proposed Infrastructure No major physical and social infrastructure is envisaged. Only drill site / well pad and temporary

camp site (Porta cabin) for the drilling of exploratory (including) appraisal wells are envisaged, which

will be dismantled after drilling of the wells.

7. Rehabilitation and resettlement (R&R) Plan If the identified lands are of private landowners then land lease mode will be applied and in case of

govt. land, land allotment from Govt. to be applied. Initially temporary and short-term lease will be

taken for 3 - 5 years for exploration purpose and in case of commercially viable discovery of

hydrocarbon resources, the land lease would be converted into long term lease up till life of the

project.

34

For sites selected are having any settlements, Resettlement & rehabilitation (R&R) plan will be

developed and implemented as per the applicable State/ Central Govt. policy. Compensation to

affected landowners for any loss of land will be ensured by Vedanta Ltd. (Cairn Oil & Gas).

Vedanta Ltd. (Cairn Oil & Gas) will ensure the livelihood of local community, if any affected by the

proposed land take, are identified and compensated through adequate compensation and other

livelihood restoration activities directly or indirectly through CSR activities.

8. Project schedule and cost estimate Vedanta Ltd (Cairn Oil and gas) has planned to carry outthe proposed project activities in theCB-

ONHP-2017/10 Block over a period of 10-12 years.

The estimated cost of the project is given below:

1) Physical Surveys Cost estimated to be approximately INR 65.821 Crore.

2) Average Cost per well for exploratory & appraisal well drilling is estimated to be INR 14

Crore.

3) Average cost of each EPU (Early Production Unit)/ QPU (Quick Production Unit) is estimated

to be INR 44.13 Crore.

9. Analysis of Proposals (Final Recommendations) The implementation of this project will not have any adverse effect on the environment as

appropriate pollution control measures will be taken from the initial stage itself.

Proposed drilling activities will result in growth of the surrounding areas by increasing direct and

indirect employment opportunities in the region.

Annexure – List of Villages

Proposed Coordinates of Exploratory & Appraisal Wells

Well id Longitude Latitude Village Taluka District State

1 71° 53' 25.979" E 24° 11' 59.463" N Navapura Deodar Banaskantha Gujarat

2 71° 56' 58.336" E 24° 12' 3.753" N Nesda nava Deesa Banaskantha Gujarat

3 71° 53' 21.250" E 24° 15' 14.267" N Dera Deodar Banaskantha Gujarat

4 71° 56' 53.696" E 24° 15' 18.568" N Dharanva Deesa Banaskantha Gujarat

5 71° 42' 38.986" E 24° 18' 15.638" N Sanav Deodar Banaskantha Gujarat

6 71° 46' 11.479" E 24° 18' 20.197" N Kuwana Deodar Banaskantha Gujarat

7 71° 49' 43.986" E 24° 18' 24.674" N Ganeshpura Tharad Banaskantha Gujarat

8 71° 53' 16.508" E 24° 18' 29.069" N Agthala Deesa Banaskantha Gujarat

9 71° 56' 49.043" E 24° 18' 33.381" N Agthala Deesa Banaskantha Gujarat

10 71° 39' 1.391" E 24° 21' 25.752" N Malupur Tharad Banaskantha Gujarat

11 71° 42' 33.959" E 24° 21' 30.405" N Padadar Tharad Banaskantha Gujarat

12 71° 46' 6.542" E 24° 21' 34.976" N Peparal Tharad Banaskantha Gujarat

13 71° 49' 39.140" E 24° 21' 39.464" N Gela Tharad Banaskantha Gujarat

14 71° 53' 11.751" E 24° 21' 43.869" N Vasna Deesa Banaskantha Gujarat

15 71° 56' 44.377" E 24° 21' 48.193" N Chekra Deesa Banaskantha Gujarat

16 71° 36' 17.467" E 24° 24' 30.373" N Chudmer Tharad Banaskantha Gujarat

17 71° 38' 56.260" E 24° 24' 40.505" N Budhanpur Tharad Banaskantha Gujarat

18 71° 42' 28.918" E 24° 24' 45.170" N Kothigam Tharad Banaskantha Gujarat

19 71° 46' 1.591" E 24° 24' 49.752" N Undrana Tharad Banaskantha Gujarat

20 71° 49' 34.279" E 24° 24' 54.252" N Bhimgadh Tharad Banaskantha Gujarat

21 71° 53' 6.981" E 24° 24' 58.668" N Detal Darbari Tharad Banaskantha Gujarat

22 71° 56' 39.696" E 24° 25' 3.002" N Bhakadiyal Deesa Banaskantha Gujarat

23 71° 36' 12.231" E 24° 27' 45.113" N Jamda Tharad Banaskantha Gujarat

24 71° 38' 51.114" E 24° 27' 55.257" N Lunal Tharad Banaskantha Gujarat

25 71° 42' 23.862" E 24° 27' 59.934" N Vedala Tharad Banaskantha Gujarat

26 71° 45' 56.626" E 24° 28' 4.527" N Khengarpura Tharad Banaskantha Gujarat

27 71° 49' 29.404" E 24° 28' 9.038" N kochala Tharad Banaskantha Gujarat

28 71° 53' 2.196" E 24° 28' 13.466" N Sidhotara Tharad Banaskantha Gujarat

29 71° 56' 35.002" E 24° 28' 17.811" N Yavarpura Deesa Banaskantha Gujarat

30 71° 36' 6.979" E 24° 30' 59.851" N Bhadodra Tharad Banaskantha Gujarat

31 71° 38' 45.952" E 24° 31' 10.007" N Hathawada Tharad Banaskantha Gujarat

32 71° 42' 18.791" E 24° 31' 14.696" N Magrol Tharad Banaskantha Gujarat

33 71° 45' 51.646" E 24° 31' 19.301" N Changada Tharad Banaskantha Gujarat

34 71° 49' 24.514" E 24° 31' 23.823" N Thara Tharad Banaskantha Gujarat

35 71° 52' 57.397" E 24° 31' 28.261" N Kiyal Tharad Banaskantha Gujarat

36 71° 56' 30.294" E 24° 31' 32.617" N Ramuna Dhanera Banaskantha Gujarat

37 71° 31' 34.961" E 24° 34' 15.106" N Jampur Tharad Banaskantha Gujarat

38 71° 35' 7.861" E 24° 34' 19.973" N Rampura Tharad Banaskantha Gujarat

39 71° 38' 40.776" E 24° 34' 24.756" N Karbun Tharad Banaskantha Gujarat

40 71° 42' 13.706" E 24° 34' 29.456" N Nana Mesara Tharad Banaskantha Gujarat

41 71° 45' 46.651" E 24° 34' 34.072" N Jadara Tharad Banaskantha Gujarat

42 71° 49' 19.611" E 24° 34' 38.606" N Morthal Tharad Banaskantha Gujarat

43 71° 52' 52.585" E 24° 34' 43.056" N Bhajna Dhanera Banaskantha Gujarat

44 71° 56' 25.573" E 24° 34' 47.422" N Vinchhivadi Dhanera Banaskantha Gujarat

45 71° 31' 29.587" E 24° 37' 29.829" N Sherau Tharad Banaskantha Gujarat

46 71° 35' 2.578" E 24° 37' 34.708" N Antrol Tharad Banaskantha Gujarat

47 71° 38' 35.584" E 24° 37' 39.503" N Naroli Tharad Banaskantha Gujarat

Well id Longitude Latitude Village Taluka District State

48 71° 42' 8.605" E 24° 37' 44.214" N Vaghasan Tharad Banaskantha Gujarat

49 71° 45' 41.642" E 24° 37' 48.842" N Kharakhoda Tharad Banaskantha Gujarat

50 71° 49' 14.692" E 24° 37' 53.387" N Virol Dhanera Banaskantha Gujarat

51 71° 52' 47.758" E 24° 37' 57.848" N Nenava Dhanera Banaskantha Gujarat

52 71° 56' 20.837" E 24° 38' 2.225" N Magarawa Dhanera Banaskantha Gujarat

53 71° 31' 24.198" E 24° 40' 44.550" N Kasavi Tharad Banaskantha Gujarat

54 71° 34' 57.280" E 24° 40' 49.441" N Takhuva Tharad Banaskantha Gujarat

55 71° 38' 30.377" E 24° 40' 54.248" N Kailashnagar Hindaun Karauli Rajasthan

56 71° 42' 3.490" E 24° 40' 58.971" N Lalpura Sujangarh Churu Rajasthan

57 71° 45' 36.618" E 24° 41' 3.611" N Gardali Sanchore Jalore Rajasthan

58 71° 49' 9.760" E 24° 41' 8.167" N Paladar Sanchore Jalore Rajasthan

59 71° 31' 18.792" E 24° 43' 59.269" N Sarawanaa Sanchore Jalore Rajasthan

60 71° 34' 51.966" E 24° 44' 4.172" N Amarpura Sanchore Jalore Rajasthan

61 71° 38' 25.155" E 24° 44' 8.991" N Chhajara Sanchore Jalore Rajasthan

62 71° 41' 58.359" E 24° 44' 13.726" N Kilawa Sanchore Jalore Rajasthan

63 71° 45' 31.579" E 24° 44' 18.378" N Itada Sanchore Jalore Rajasthan

64 71° 49' 4.813" E 24° 44' 22.945" N Jajoosan Sanchore Jalore Rajasthan

65 71° 31' 13.371" E 24° 47' 13.987" N Kesoori Sanchore Jalore Rajasthan

66 71° 34' 46.637" E 24° 47' 18.902" N Janvi Sanchore Jalore Rajasthan

67 71° 38' 19.918" E 24° 47' 23.733" N Vishnu nagar Sanchore Jalore Rajasthan

68 71° 41' 53.214" E 24° 47' 28.480" N Dadoosan Sanchore Jalore Rajasthan

69 71° 45' 26.526" E 24° 47' 33.143" N Siddheshwar Sanchore Jalore Rajasthan

70 71° 48' 59.852" E 24° 47' 37.721" N Phalna Sanchore Jalore Rajasthan

Note: - Actual geo-graphical surface coordinates of exploratory and appraisal well locations within 2000m radius of the proposed coordinates.

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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 mustbe part of single pdf document.

(I) Basic InformationS.No. Item Details

Whether it is a violation case and applicationis being submitted under Notification No.S.O.804(E) dated 14.03.2017 ?

No

1.

Name of the Project/sOnshore Oil and Gas Exploration and Appraisal in CB-ONHP-2017/10 block in Banaskantha District of Gujarat and JaloreDistrict of Rajasthan.

Brief summary of project Annexure-Brief summary of projectProposal Number IA/GJ/IND2/100119/2019Project Cost (in lacs) 166364.1

2.S. No. in the schedule 1(b) Offshore and onshore oil and gas exploration,

development & productionProject Sector Industrial Projects - 2

3.Proposed capacity/area/length/tonnage to behandled/command area/lease area/numberor wells to be drilled

2766 km sq /70 wells ha.

4. New/Expansion/Modernization New

5. Existing Capacity/Area etc. 0 ha.

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

7.Does it attract the general condition? If yes,please specify Yes

d) Inter-State boundaries and international boundaries

8. Does it attract the specific condition? If yes,please specify No

9.Location of the project Banaskantha District of Gujarat and Jalore District of

RajasthanShape of the project land Block (Polygon)

Uploaded GPS file Annexure-GPS file Uploaded copy of survey of India Toposheet Annexure-Survey of india toposheetPlot/Survey/Khasra No. 40P9, 40O10, 40P11, 40P13, 40P14, 40P15, 40P16Town / Village Annexure - List of VillagesState of the project Gujarat

Details of State of the project

S.no State Name District Name Tehsil Name

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(1.) Gujarat Banaskantha Tharad

(2.) Gujarat Banaskantha Dhanera

(3.) Gujarat Banaskantha Deesa

(4.) Gujarat Banaskantha Deodar

(5.) Rajasthan Churu Sujangarh

(6.) Rajasthan Karauli Hindaun

(7.) Rajasthan Jalore Sanchore

10.Nearest railway station along with distancein kms Bhildi Railway Station, 0.9 km

Nearest airport along with distance in kms Ahmedabad Airport, 137 km

11. Nearest Town/City/District Headquartersalong with distance in kms Tharad , 0 km

12.Village Panchayats, Zila Parishad, MuncipalCorporation, Local body (Complete postaladdress with telephone nos. to be given)

District Panchayat Banaskantha, Joravar Palace, Palanpur -385001. District Panchayat, Jalore Jalore, Rajasthan – 343001

13. Name of the Applicant Mayank

14. Registered Address DLF Atria, Phase 2, Jacaranda Marg, DLF City

15.

Address for correspondance:Name of the Company M/s Vedanta Limited(Division Cairn Oil & Gas)Name of the Applicant MayankDesignation (Owner/ Partner/ CEO) engPin code 122002E-mail mayank.sharma@cairnindia.comTelephone No. 0124-4594176Fax No. 0124-Copy of documents in support of thecompetence/authority of the person makingthis application to make application on behalfof the User Agency .

NIL

16. Details of Alternative Sites examined, if any.Location of these sites should be shown on atoposheet

No

17. Whether part of Interlinked projects? No

18. Whether separate application of Interlinkedproject has been submitted? N/A

19. If Yes, MoEF file number N/ADate of submission N/A

20. If No, Reason N/A

21. Whether the proposal involves Approval/ Clearance under: if yes, details of the same and theirstatus to be given(i) Whether the proposal involvesapproval/clearance under the Forest(Conservation) Act,1980?

No

(ii) Whether the proposal involvesapproval/clearance under the wildlife(Protection) Act,1972?

No

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(iii) Whether the proposal involvesapproval/clearance under the C.R.Znotification, 2011?

No

22. Whether there is any GovernmentOrder/Policy relevant/relating to the site? No

23. Whether any Forest Land Involved? NoArea of Forest land Involved (hectares) N/A

24. Whether there is any litigation pendingagainst the project and/or land in which theproject is proposed to be set up?

No

(a) Name of the Court N/A(b) Name of the Sub court N/A(c) Case No. N/A(d) Orders/directions of the court, if any andrelevance with the proposed project N/A

(II) Activity

1 Construction, operation or decommissioning of the Project involving actions, which will causephysical changes in the locality (topography, land use, changes in water bodies, etc.)

S.NoInformation/Checklist confirmation Yes/No

Details there of (with approximatequantities/rates, wherever possible) with

source of information data

1.1

Permanent or temporary change in land use,land cover or topography including increasein intensity of land use (with respect to localland use plan)

Yes

Exploratory & appraisal wells will be drilled. The typicalarea required for each well pad (drill site) will be approx.300m x 300m. RoU of 30 m (approx.) width foraccommodating suitable access roads connecting to wellpads (drill sites), OHL and other utilities in future.

1.2 Clearance of existing land, vegetation andbuildings? Yes Minimum clearing of vegetation is envisaged.

1.3 Creation of new land uses? Yes

Drilling of exploratory and appraisal wells will be atemporary activity, However in case of commerciallyviable discovery of hydrocarbon, the sites shall continuetill the end of the field life.

1.4 Pre-construction investigations e.g. borehouses, soil testing? Yes Bore wells and soil testing will be undertaken prior to

construction of new well.

1.5 Construction works? Yes

For exploratory wells, site preparation will be done intypical area of ~300m x ~300m for setting up of adrilling rig to enable drilling and testing of wells.Temporary storage facilities will be provided withindesignated sites for evacuation of well fluid. RoU of 30 m(approx.) width for accommodating suitable accessroads connecting to well pads (drill sites), OHL and otherutilities in future.

1.6 Demolition works? No Not applicable

1.7 Temporary sites used for construction worksor housing of construction workers? Yes

No housing for construction workers is envisagedTemporary camp (mobile porta cabin) sites will be usedfor installation of mobile bunk houses for the workersduring drilling campaign.

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1.8Above ground buildings, structures orearthworks including linear structures, cutand fill or excavations and fill or excavations

Yes

Above ground temporary structures like drilling rig, DGstack will be set up during drilling. Site developmentworks will include: Filling of earth and leveling forsetting up the well. Impervious pits for temporarystorage of drill cuttings and excess drill mud,wastewater and others.

1.9 Underground works including mining ortunnelling? No

There are no mining or tunneling works however drillingof exploratory well involves drilling through sub-surfacelayers till the targets depth is reached. During drilling,casing & cementing is carried out simultaneously tosecure the well.

1.10 Reclamation works? Yes

At the end of the field life and unsuccessful drilling,decommissioning of the onshore drill sites would beundertaken and the land would be restored to its bestachievable original condition as practically possible.

1.11 Dredging? No Not applicable

1.12 Offshore structures? No Not applicable as the entire well is onshore.

1.13 Production and manufacturing processes? Yes

In case of commercial viable discovery of hydrocarbon,EPUs/ QPUs will be installed for the processing ofproduced well fluid. An EPU/ QPU will be a packaged/modular mobile unit consists of 3-phase separator,heater, oil storage tanks, PW separation & disposalsystem power generation (GEG/DG) and others. EachEPU/ QPU capacity will be~2000 BFPD.

1.14 Facilities for storage of goods or materials? Yes

At the exploration & appraisal wells, there will betemporary storage of drilling essentials. In case ofcommercially viable discovery of hydrocarbons, duringthe early production stage adequate facilities for storageof goods & materials will be established

1.15 Facilities for treatment or disposal of solidwaste or liquid effluents? Yes

Drilling mud will be treated onsite for max. reuse. SpentWBM (approx. 250 to 500 m3/well) and drill cuttingsassociated with WBM (approx. 250 to 750 Tons/well) &SBM (approx. 500 to 1500 Tons/well) will be temporarilystored in HDPE lined pits. Drill cuttings, spent mud, usedoil & other hazardous waste will be disposed as perHazardous & Other Wastes Rules, 2016. Drilling washwastewater (approx. 30 - 40 m3/day) -collected in linedimpervious pits. Domestic wastewater (approx. 15 t

1.16 Facilities for long term housing ofoperational workers? No No long term housing requirements are envisaged for

the proposed activities.

1.17 New road, rail or sea traffic duringconstruction or operation? Yes

Access roads will be made/existing access road will bestrengthened (if needed) to support exploratory andappraisal drilling activities. No rail traffic interference isexpected.

1.18

New road, rail, air water borne or othertransport infrastructure including new oraltered routes and stations, ports, airportsetc?

Yes

Access roads will be made/existing access road will bestrengthened (if needed) to support exploratory andappraisal drilling activities. No rail traffic interference isexpected.

1.19Closure or diversion of existing transportroutes or infrastructure leading to changesin traffic movements?

No Not Applicable

1.20 New or diverted transmission lines orpipelines? No New or diverted transmission lines or pipelines (cross-

country) are not envisaged.

1.21 Impoundment, damming, culverting, Yes Necessary culverts will be ensured for hydrology of

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realignment or other changes to thehydrology of watercourses or aquifers?

water courses during access roads construction to wellpads.

1.22 Stream crossings? No Not Applicable.

1.23 Abstraction or transfers of water fromground or surface waters? No

For seismic surveys, water requirement will be 20 - 30m3/day for domestic use. For drilling activities, waterrequirement will be of 750 – 1300 m3/well (for mudpreparation); 25 – 50 m3/day/well (for miscellaneousactivities) and 20 - 30 m3/day/well (domestic use).During the early production phase, for each typical EPU/QPU location, water requirement will be 15 – 18m3/day. Water source: locally through approved/authorized sources of SW or GW (after obtainingpermission from CGWA/ State

1.24 Changes in water bodies or the land surfaceaffecting drainage or run-off? No Not envisaged.

1.25 Transport of personnel or materials forconstruction, operation or decommissioning? Yes Transportation of personnel and materials for well pads

construction, drilling, etc

1.26 Long-term dismantling or decommissioningor restoration works? Yes

At the end of the field life and abandoned drilling sites,decommissioning will be undertaken as per guidelines ofDGH, MoP&NG.

1.27Ongoing activity during decommissioningwhich could have an impact on theenvironment?

No

At the end of field life the decommissioning will be takenup. The decommissioning stage will involve increase invehicular traffic, thereby contributing to fugitiveemissions in the form of vehicular emissions and dustgeneration. Introduction of vehicular traffic on the siteapproach & access roads may result in increased noiselevels in areas adjacent to the roads. However it will betemporary in nature

1.28 Influx of people to an area in eithertemporarily or permanently? Yes

Temporary influx of population is likely to occur duringall phases of the project life cycle. However, for most ofthe construction works the local villagers would beemployed. For the technical jobs highly technical andtrained workforce would be sourced from outside basedon experience of working in the field of hydrocarbonexploration and production. No long term housingfacilities are envisaged for the project and mostly localpersonnel will be employed as construction workers.

1.29 Introduction of alien species? No Not Applicable

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

1.31 Any other actions? No Not Applicable

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

S.NoInformation/Checklist confirmation Yes/No

Details thereof (with approximatequantities/rates, wherever possible) with

source of information data

2.1 Land especially undeveloped or agriculturalland (ha) Yes

Land requirement will be for: I. Typical Size of 300 m x300 m (approx.) for each one well pad (drill site); II.RoU of 30 m (approx.) width for accommodating suitableaccess roads connecting to well pads, OHL and otherutilities in future.

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2.2 Water (expected source & competing users)unit: KLD

Yes For seismic surveys, water requirement: 20 - 30 m3/dayfor domestic use. For drilling activities, waterrequirement will be of 750 – 1300 m3/well (for mudpreparation); 25 – 50 m3/day/well (for miscellaneousactivities) and 20 - 30 m3/day/well (domestic use).During the early production phase, for each typical EPU/QPU location, water requirement will be 15 – 18m3/day. Water source: locally through approved/authorized sources of SW or GW (after obtainingpermission from CGWA/ State

2.3 Minerals (MT) No Not applicable

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

For setting up of an onshore well pad, the indicativequantities required include the following 1. RCC : 750m3 2. Rebar: 90 MT 3. Sand: 50,000 m3 4. Stoneaggregates: 7500 m3 5. Brick/rubble masonry: Asrequired Note: The quantities are indicative and maychange depending upon site conditions/ equipment type/size/ratings etc. which shall be firmed up during detailedengineering/execution of the project.

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

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

Yes

For drilling activity of a well, power requirement will besourced through diesel generators of 3 x 1000 kVA (twoworking + one standby), 2 x 350 kVA (one working +one standby) and 2 x 100 kVA (one working + onestandby). Fuel requirement for DG sets will beapproximately 10 KLD of HSD. For the early production,power requirement will be met through state electricitygrid and/ or installation of Diesel/ Gas EngineGenerator(s) using produced (associated) natural gas.

2.7 Any other natural resources (use appropriatestandard units) No Not applicable

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

S.NoInformation/Checklist confirmation Yes/No

Details thereof (with approximatequantities/rates, wherever possible) with

source of information data

3.1

Use of substances or materials, which arehazardous (as per MSIHC rules) to humanhealth or the environment (flora, fauna, andwater supplies

Yes Crude oil Diesel Drilling muds and related chemicals

3.2Changes in occurrence of disease or affectdisease vectors (e.g. insect or water bornediseases)

No None

3.3 Affect the welfare of people e.g. by changingliving conditions? Yes

Local/nearby personnel will be utilized during sitepreparation, drilling and decommissioning phases ofonshore well pads. The activity would generate direct &indirect employment opportunities for local nearbypeople. CSR measures will be taken up by Vedanta Ltd(Cairn Oil & Gas) in case of commercially viablehydrocarbon discovery & further full-fledgeddevelopment of the fields and production and associatedfacilities.

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3.4 Vulnerable groups of people who could beaffected by the project e.g. hospital patients,children, the elderly etc.

No Not anticipated

3.5 Any other causes No None

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

S.NoInformation/Checklist confirmation Yes/No

Details thereof (with approximatequantities/rates, wherever possible) with

source of information data

4.1 Spoil, overburden or mine wastes Yes Generation of drill cuttings associated with WBM will beapprox. 250-750 tons per well.

4.2 Municipal waste (domestic and orcommercial wastes) Yes

During drilling for 60 to 90 days per well, it is expectedthat approximately 25-35 kg per day of kitchen wasteswill be generated from well sites. Biodegradable foodwaste generated from onshore well pads will be disposedsuitably. Other waste generation will includeapproximately 20 kg per day of non-combustible non-hazardous waste/scraps which will be disposed suitable.

4.3 Hazardous wastes (as per Hazardous WasteManagement Rules) Yes

Drill cuttings associated with SBM: ~500-1500 Tons perwell Residual drilling mud (WBM): ~250-500 Tons perwell Used lubricant oil: ~1-2 Tons per well All drillcuttings, spent mud and used oil and other hazardouswaste will be disposed as per Hazardous and OtherWastes (Management and Transboundary Movement)Rules, 2016.

4.4 Other industrial process wastes No Not applicable

4.5 Surplus product No Not applicable

4.6 Sewage sludge or other sludge from effluenttreatment Yes

Sewage sludge/ STP sludge, ETP sludge & oily sludge areenvisaged. STP sludge will be utilized as manure. While,ETP sludge & oily sludge will be disposed as perHazardous and Other Wastes (Management andTransboundary Movement) Rules, 2016.

4.7 Construction or demolition wastes Yes

Waste concrete would be generated at the time ofconstruction of wells. These waste will be handled as perConstruction and Demolition Waste Management Rules2016

4.8 Redundant machinery or equipment No Not applicable

4.9 Contaminated soils or other materials No Not applicable

4.10 Agricultural wastes No Not applicable

4.11 Other solid wastes YesOther solid waste like lead acid batteries, scrap metal,etc. generated will be recycled through authorizedrecyclers.

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

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S.No Information/Checklist confirmation Yes/No Details thereof (with approximatequantities/rates, wherever possible) with

source of information data

5.1 Emissions from combustion of fossil fuelsfrom stationary or mobile sources Yes

Exhaust emissions are expected from diesel generatorsto be used for the operation of drilling activities.Emissions are also expected from flaring of gases duringtesting/ extended testing of exploratory and appraisalwells. Vehicular emissions are likely to occur during thetransportation of construction materials, equipment andworkforce.

5.2 Emissions from production processes Yes

Emissions due to D.G. set or GEG & flaring of gas duringwell fluid processing (oil & gas, produced waterseparation) and longer duration/ extended testing ofwells are envisaged.

5.3 Emissions from materials handling includingstorage or transport Yes

Fugitive emissions in the form of dust are likely to begenerated during material handling for onshore well padconstruction/ drilling and decommissioning phases.Minor fugitive emissions of VOCs may result fromhydrocarbons handling system of crude oil and diesel.

5.4 Emissions from construction activitiesincluding plant and equipment Yes Fugitive emissions are likely to occur during initial site

preparation and also due to vehicular movement.

5.5Dust or odours from handling of materialsincluding construction materials, sewage andwaste

YesDust is likely to be generated from the handling ofconstructional materials viz. cement, sand, etc. Someodour may be generated from well fluid handling.

5.6 Emissions from incineration of waste No Not applicable

5.7 Emissions from burning of waste in open air(e.g. slash materials, construction debris) No Not applicable

5.8 Emissions from any other sources No Not applicable

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

S.NoInformation/Checklist confirmation Yes/No

Details thereof (with approximatequantities/rates, wherever possible) with

source of information data

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

The operations of drilling rig and associated machineryincluding diesel generators will lead to noise emissions.The diesel generators would be provided with acousticenclosures to comply with the regulatory requirements.

6.2 From industrial or similar processes No Not applicable

6.3 From construction or demolition YesNoise will occur from operation of constructionequipment like loaders, tippers, bull dozers etc., foronshore well pads

6.4 From blasting or piling Yes During seismic surveys, shot hole drilling & blastingactivities will generate short term & transient noise.

6.5 From construction or operational traffic Yes Movement of vehicular traffic accessing the well padsites will result in increase in background noise levels.

6.6 From lighting or cooling systems No No noticeable noise is anticipated due to lighting.

6.7 From any other sources No Not Applicable

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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.NoInformation/Checklist confirmation Yes/No

Details thereof (with approximatequantities/rates, wherever possible) with

source of information data

7.1 From handling, storage, use or spillage ofhazardous materials Yes

Potential risks include: Spillage of crude oil/diesel Sub-surface contamination due to spillage of crude, diesel,lube oil.

7.2From discharge of sewage or other effluentsto water or the land (expected mode andplace of discharge)

Yes

For seismic & drilling activities, domestic wastewater willbe treated with mobile STP and will be utilized for dustsuppression, green belt, etc. Drilling wash wastewaterwill be stored in lined impervious pits and will be treatedprior to discharge in order to comply with the regulatorystandards. Treated effluent (PW) will be disposed offusing either a nearby down hole disposal well or otheravailable & suitable onshore disposal medium or solar/mech. evaporators depending on feas

7.3 By deposition of pollutants emitted to air intothe land or into water No Not envisaged

7.4 From any other sources No Not expected

7.5Is there a risk of long term build up ofpollutants in the environment from thesesources?

No Mitigation measures will be in place to avoid any risk oflong term build-up of pollutants in the environment.

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

S.NoInformation/Checklist confirmation Yes/No

Details thereof (with approximatequantities/rates, wherever possible) with

source of information data

8.1From explosions, spillages, fires etc fromstorage, handling, use or production ofhazardous substances

Yes

Potential risks include well blowout due to abnormalreservoir pressure encountered during drilling of a wellwhich may result in explosion, fire and spillage. Tominimize such risk, blowout preventers and othermitigation measures will be in place.

8.2 From any other causes YesRisk of physical injuries during construction activities inonshore regions Adequate mitigation measures will be inplace

8.3

Could the project be affected by naturaldisasters causing environmental damage(e.g. floods, earthquakes, landslides,cloudburst etc)?

Yes Natural disasters pose potential risk. EmergencyResponse and Disaster Management Plan will be in place

9Factors which should be considered (such as consequential development) which could lead toenvironmental effects or the potential for cumulative impacts with other existing or plannedactivities in the locality

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

quantities/rates, wherever possible) withsource of information data

9.1 Lead to development of supporting utilities, Yes The exploratory (including appraisal) drilling activity is a

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ancillary development or developmentstimulated by the project which could haveimpact on the environment e.g.:

Supporting infrastructure (roads, powersupply,waste or waste water treatment,etc.)housing developmentextractive industriessupply industriesOther

temporary project activity of short duration. In an eventof a discovery of a hydrocarbon field, there could becommercial exploitation.

9.2 Lead to after-use of the site, which couldhave an impact on the environment No

Abandoned drilling sites & Upon exhausting ofcommercially exploitation of hydrocarbon resources, allstructures and facilities will be demolished anddemobilized as per guidelines of DGH, MoP&NG, DGMS.

9.3 Set a precedent for later developments YesA precedence of additional peripheral development mayhappen in case of commercially viable hydrocarbondiscovery

9.4Have cumulative effects due to proximity toother existing or planned projectswith similar effects

No Currently, no other major development is anticipated.

(III) Environmental Sensitivity

S.No Areas Name/Identity Aerial distance (within 15km.) Proposedproject location boundary

1

Areas protected under internationalconventions, national or local legislation for their ecological, landscape, cultural or otherrelated value

No Not applicable

2

Areas which are important or sensitive forecological reasons - Wetlands, watercoursesor other water bodies, coastal zone,biospheres, mountains, forests

No Not applicable

3

Areas used by protected, important orsensitive species of flora or fauna forbreeding, nesting, foraging, resting, overwintering, migration

Yes

Luni River - Flowing within the block from west toeast on North side of the Block boundary BanasRiver - Flowing at 5.3Km, South from the blockboundary

4 Inland, coastal, marine or undergroundwaters No Not Applicable

5 State, National boundaries No Gujarat and Rajasthan State Boundary passingthrough the block

6Routes or facilities used by the public foraccess to recreation or other tourist, pilgrimareas

No Not applicable

7 Defence installations No Not applicable

8 Densely populated or built-up area Yes Tharad, Gujarat - Located within the blockSanchore, Rajasthan - Located within the block

9 Areas occupied by sensitive man-made landuses (hospitals, schools, places of worship,

Yes Such places are located within the block boundary

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community facilities)

10Areas containing important, high quality or scarceresources.(ground water resources,surfaceresources,forestry,agriculture,fisheries,tourism,minerals)

No Not applicable

11Areas already subjected to pollution orenvironmental damage.(those where existinglegal environmental standards are exceeded)

No Not applicable

12

Areas susceptible to natural hazard whichcould cause the project to presentenvironmental problems (earthquakes,subsidence, landslides, erosion, flooding orextreme or adverse climatic conditions)similar effects

NoThe area under study falls in Zone-III (moderaterisk), according to the Indian Standard SeismicZoning Map

(IV) Proposed Terms of Reference for EIA studies

1 Uploaded Proposed TOR File Annexure-TOR file

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

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

4 Uploaded additional attachments(onlysingle pdf file) Annexure-Additional attachments

(V) UndertakingI hereby give undertaking that the data and information given in the application and enclosures aretrue to be best of my knowledge and belief and I am aware that if any part of the data andinformation found to be false or misleading at any stage, the project will be rejected and clearancegiven, if any to the project will be revoked at our risk and cost.

V.(i)

Name of Applicant MayankDesignation engName of Company (Applicant Nameshould not be given here) M/s Vedanta Limited(Division Cairn Oil & Gas)

Address DLF Atria, Phase 2, Jacaranda Marg, DLF City

In this regard, under the provisions of the EIA Notification 2006 as amended, the Standard TOR

for the purpose of preparing environment impact assessment report and environment

management plan for obtaining prior environment clearance is prescribed with public consultation

as follows:

STANDARD TERMS OF REFERENCE (TOR) FOR EIA/EMP REPORT FOR PROJECTS/ACTIVITIES REQUIRING ENVIRONMENT CLEARANCE

1(b):STANDARD TERMS OF REFERENCE FOR CONDUCTING

ENVIRONMENT IMPACT ASSESSMENT STUDY FOR OFFSHORE AND ONSHORE OIL AND GAS EXPLORATION, DEVELOPMENT AND PRODUCTION PROJECTS AND INFORMATION TO BE INCLUDED IN EIA/EMP REPORT

B . STANDARD TOR FOR ONSHORE OIL AND GAS EXPLORATION, DEVELOPMENT

& PRODUCTION

1. Executive summary of a project.

2. Project description, project objectives and project benefits.

3. Cost of project and period of completion.

4. Site details within 1 km of the each proposed well, any habitation, any other installation/activity, flora and fauna, approachability to site, other activities including agriculture/land, satellite imagery for 10 km area. All the geological details shall be mentioned in the Topo sheet of 1:40000 scale, superimposing the well locations and other structures of the projects. Topography of the project site.

5. Details of sensitive areas such as National Park, Wildlife sanctuary and any other eco-sensitive area alongwith map indicating distance.

6. Approval for the forest land from the State/Central Govt. under Forest (Conservation) Act, 1980, if applicable.

7. Recommendation of SCZMA/CRZ clearance as per CRZ Notification dated 6th January, 2011 ( if applicable).

8. Distance from nearby critically/severely polluted area as per Notification, if applicable. Status of moratorium imposed on the area.

9. Does proposal involve rehabilitation and resettlement? If yes, details thereof.

10. Environmental considerations in the selection of the drilling locations for which environmental clearance is being sought. Present any analysis suggested for minimizing the foot print giving details of drilling and development options considered.

11. Baseline data collection for air, water and soil for one season leaving the monsoon season in an area of 10 km radius with centre of Oil Field as its centre covering the area of all proposed drilling wells.

12. Climatology and Meteorology including wind speed, wind direction, temperature rainfall relative humidity etc.

13. Details of Ambient Air Quality monitoring at 8 locations for PM2.5, PM10, SO2, NOx, CO, VOCs, Methane and non-methane HC.

14. Soil sample analysis (physical and chemical properties) at the areas located at 5 locations.

15. Ground and surface water quality in the vicinity of the proposed wells site.

1

STANDARD TERMS OF REFERENCE (TOR) FOR EIA/EMP REPORT FOR PROJECTS/ ACTIVITIES REQUIRING ENVIRONMENT CLEARANCE

16. Measurement of Noise levels within 1 km radius of the proposed wells.

17. Vegetation and land use; flora/fauna in the block area with details of endangered species, if any.

18. Incremental GLC as a result of DG set operation, flaring etc.

19. Potential environmental impact envisaged during various stages of project activities such as site activation, development, operation/ maintenance and decommissioning.

20. Actual source of water and 'Permission' for the drawl of water from the Competent Authority. Detailed water balance, wastewater generation and discharge.

21. Noise abatement measures and measures to minimize disturbance due to light and visual intrusions.

22. Details on wastewater generation, treatment and utilization /discharge for produced water/ formation water, cooling waters, other wastewaters, etc. duringallprojectphases.

23. Details on solid waste management for drill cuttings, drilling mud and oil sludge, produced sand, radio activematerials, other hazardous materials, etc. including its disposal options during all project phases.

24. Disposal of spent oil and lube.

25. Storage of chemicals and diesel at site. Hazardous material usage, storage and accounting.

26. Commitment for the use of water based mud (WBM) only

27. Oil spill emergency plans for recovery/ reclamation.

28. H2S emissions control.

29. Produced oil/gas handling, processing and storage/transportation.

30. Details of control of air, water and noise pollution during production phase.

31. Measures to protect ground water and shallow aquifers from contamination.

32. Whether any burn pits being utilised for well test operations.

33. Risk assessment and disaster management plan for independent reviews of well designed construction etc. for prevention of blow out. Blowout preventer installation.

34. Environmental management plan.

35. Total capital and recurring cost for environmental control measures.

36. Emergency preparedness plan.

37. Decommissioning and restoration plans.

38. Documentary proof of membership of common disposal facilities, if any.

39. Details of environmental and safety related documentation within the company including documentation and proposed occupational health and safety Surveillance Safety Programme for all personnel at site. This shall also include monitoring programme for the environmental.

40. A copy of Corporate Environment Policy of the company as per the Ministry's O.M. No. J-11013/ 41/2006-IA.II(I) dated 26th April, 2011 available on the Ministry's website.

41. Any litigation pending against the project and or any direction/order passed by any court of law against the project. If so details thereof.

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