Draft Environment Impact Assessment Report For Onshore Oil

Draft Environment Impact Assessment Report

For

Onshore Oil & Gas Exploration of 46 wells in 12 ML

Blocks of Western Onshore Basin, District Mehsana,

Gujarat

Submitted By

Oil and Natural Gas Corporation Limited

Corporate Health, Safety and Environment,

3rd Floor, Tower A, Deendayal Urja Bhawan,

Plot No.5, Vasant Kunj, Nelson Mandela Marg,

New Delhi-110070

Draft Environmental Impact Assessment Report

for

Onshore Oil & Gas Exploration of 46 wells in 12 ML Blocks of

Western Onshore Basin, District Mehsana, Gujarat

Submitted By

Oil and Natural Gas Corporation Limited

Corporate Health, Safety and Environment,

3rd Floor, Tower A, Deendayal Urja Bhawan,

Plot No.5, Vasant Kunj, Nelson Mandela Marg,

New Delhi-110070

(I) Declaration by Experts contributing to the EIA

I, hereby, certify that I was a part of the EIA team in the following capacity that developed

the above EIA.

EIA coordinator: Name: Harendra Singh

Signature and Date:

Period of involvement: July 2018 till date

Functional area experts:

S. no. Functional

Area

Name of the

Experts

Involvement

(Period and task)

Signature

1. 1

.

AP* Vartika Roy AAQ monitoring plan,

impact prediction &

management plan studies

(July’2018 till date)

2. 2 WP* B.P.Babu/Ashish

Bhuwan

Water Pollution monitoring,

Prevention and Control

studies (July’2018 till date)

3. 4 SE* S.K.Mohapatra Socioeconomic study


4. 5 EB* Dr. Archana Yadav Ecology & Biodiversity


5. 6 HG* Debashis

Chakraborty

Hydrology Studies


6. 7 GEO* Debashis

Chakraborty

Geology studies (July’2018

till date)

7. 8 SC* R R Dwivedi Soil Quality, impacts and

conservation measures


8. 9 AQ* Setu Goyal Air quality assessment


9. 1

0

NV* D.K.Trivedi Noise/Vibration Studies


10. 1

1

LU* Nilay Meshram Land Use Studies


11. 1

2

RH* Amlan Chakraborty Risk Assessment and

DMP studies (July’2018 till

date)

Team Members:, Mrs. Alaknanda Dubey and Mr. Vipul Sharma

(II) Declaration by the Head of the accredited consultant organization/

authorized person

I, Harendra Singh, hereby, confirm that the above mentioned experts prepared the EIA

“Onshore Oil & Gas Exploration of 46 wells in 12 ML blocks in Mehsana district,

Gujarat”. I also confirm that the consultant organization shall be fully accountable for

any mis-leading information mentioned in this statement.

Signature:

Name: Harendra Singh

Designation: General Manager

Name of the EIA consultant organization: Oil & Natural Gas Corporation Ltd.

NABET Certificate No. & Issue Date: NABET/EIA/1518/RA0054, 14/06/2017

(III) Document No. ONGC/CHSE/EIA/WOB/2018-19/01

(IV) Review and Revision History

History of revisions of the present report

Rev Date Modifications

Rev. 00 Draft 20/12/2018 Preliminary Draft EIA Report

Rev.01 Draft 31/12/2018 Draft EIA report for Reviewer Comments

Rev. 02 Draft 08/01/2019 Final Draft EIA report

Review DATE DESCRIPTION REVIEWER-1 REVIEWER-2

Review. 00

Draft

20/12/2018 Preliminary

Draft EIA

Report

Mr. Golap C

Boruah

Mr. Rajeeva Kumar

Review.01

Draft

31/12/2018 Draft EIA

report for

Reviewer

Comments

Mr. Rajeeva

Kumar

Dr. Naveen Raj

Review.02

Draft

07/01/2019 Final Draft EIA

Report

Mr. M.K.Garg Mr. Randhir

Chakravarti

Onshore Oil & Gas Exploration of 46 wells in 12 ML Blocks of Western Onshore Basin , District Mehsana, Gujarat

Doc. No. ONGC/CHSE/EIA/WOB/2018-19/01 Rev. No. 02 Issue date 08/01/2019 Chapter No.

TABLE OF CONTENTS

TABLE OF CONTENTS

Abbreviations & Glossary i-ix

ToR Compliance x-xiv

Executive Summary xv-xxx

CHAPTER-1: INTRODUCTION

1.0 Introduction 2

1.1 Purpose of the Report 2

1.2 Identification of Project and Project Proponent 3

1.2.1. Identification of the Project 3

1.2.2. Project Proponent 3

1.2.3. Proposed Project 3

1.3 Brief Description of the Project 4

1.3.1. Nature of the Project 4

1.3.2. Size of the Project 4

1.3.3. Project Site Details 4

1.3.4 Importance of the Project 13

1.4 Scope of the Study 14

1.4.1 Administrative and Legislative Background 15

1.4.2 Study Area for EIA 15

1.4.3 Methodology of the Study 15

1.5 Contents of the Report 17

1.6 Status and Stage of Regulatory Framework 19



TABLE OF CONTENTS

CHAPTER-2: PROJECT DESCRIPTION

2.1 Introduction 21

2.2 Type of the Project 21

2.3 Need Of the Project 21

2.4 Project Location and Project Detail 22

2.4.1 Typical Well site details 22

2.5 Size or Magnitude of Operation 23

2.5.1 Resource Requirement for the Project 24

2.5.1.1 Land Requirement 24

2.5.1.2 Water Requirement 24

2.5.1.3 Power Requirement 26

2.5.1.4 Man Power Requirement 27

2.5.1.5 Drilling Mud 27

2.6 Proposed Schedule for the Project Approval and Implementation 28

2.7 Technology and Drilling Process Description 29

2.7.1 Drilling of Exploratory well 30

2.7.2 Proposed Hole Size / Casing Programme 32

2.7.3 Surface Testing & Flaring 32

2.8 Details of Project Utilities 33

2.8.1 Site Preparation 33

2.8.2 Approach Roads 33

2.8.2.1 Installation of Facilities 34

2.9 Post Drilling Operations - Abandonment and Restoration 40

2.9.1 Demobilization & Decommissioning 40

2.9.2 Restoration of Well Sites 40



TABLE OF CONTENTS

2.9.3 Traffic Volumes 41

2.10 Sources of Pollution 42

2.10.1 General 42

2.10.2 Wastewater Generation and Disposal 42

2.10.3 Air Emissions 43

2.10.4 Solid Waste 44

2.10.4.1 Drilling Mud 44

2.10.4.2 Drill Cuttings 44

2.10.4.3.Waste Pit Details 45

2.10.4.4 Used/Spent Oil 45

2.10.4.5 Drilling Mud & Drill Cuttings Analysis 45

2.10.5 Noise Levels 46

2.11 Qualifications, Skills and Training Practice 47

CHAPTER-3: DESCRIPTION OF THE ENVIRONMENT

3.1 Baseline Environmental Study 51

3.2 Geology 52

3.3 Hydrogeology 53

3.3.1 Ground Water Resources 54

3.4 Seismicity and Floods 56

3.5 Land Environment 58

3.5.1 Topography 58

3.5.2 Land Use Studies 58

3.5.2.1 Methodology 58

3.6 Meteorology 61

3.6.1 Meteorological data recorded at study area 61



TABLE OF CONTENTS

3.6.2 Secondary Data from Indian Meteorological Dept., (IMD), Ahmedabad 63

3.7 Ambient Air Quality 67

3.7.1 Selection of Sampling Locations 67

3.7.2 Frequency and Parameters for Sampling 67

3.7.3 Instruments used for Sampling 68

3.7.4 Sampling and Analytical Techniques 68

3.7.5 Ambient Air Quality Results 72

3.7.6 Summary of Ambient Air Quality Results 72

3.7.7 Observations 73

3.8 Noise Environment 76

3.8.1 Methodology for Noise Monitoring 76

3.8.2 Details of Noise Monitoring Locations & Presentations of Results 77


3.9 Water Environment 85

3.9.1 Reconnaissance of study area 85

3.9.2 Water Quality Monitoring 85

85 3.9.3 Sampling and Analysis Techniques 85

3.9.4 Details of water Sampling Locations 85

3.9.5 Presentation of Results 88


3.10 Soil Quality 110

3.10.1 Sampling and Analysis Techniques 110

3.10.2 Details of Soil Sampling Locations 110

3.10.3 Presentation of Results 111


3.11 Biological Environment 116

3.11.1 Introduction 116



TABLE OF CONTENTS

3.11.2 Reconnaissance of study area 116

3.11.3 Assessment of Flora 116

3.11.4 Vegetation of Study Area 121

3.11.5 Assessment of Fauna 122

3.11.6 Aquatic Ecology 128

3.11.6.1 Sampling Procedure 128

3.11.6.2 Method of Analysis 128

3.11.6.3 Species Diversity 129

3.11.7 Conclusion 133

3.12 Socio-economic Environment 134

3.12.1 Baseline Status 134

3.12.2 Methodology for Primary Data Collection 135

3.12.3 Demography 135

3.12.4 Literacy 137

3.12.5 Urban/Rural Population Mehsana district 138

3.12.6 Social Structure 138

3.12.7 Occupational Structure 139

3.12.8 Infrastructure Facilities 140

3.12.8.1 Educational Facilities 140

3.12.8.2 Health Facilities in Rural Area 141

3.12.9 Drinking Water facility in the rural villages of the study area 141

3.12.10 Public Consultation during Primary Survey 142

3.12.11 Salient Observations of the study 143

3.12.12 Economic Profile 145

3.12.13 Cultural & Aesthetic attributes 146

3.12.13.1 Festival celebrated in the study area 146

3.12.14 Community Consultation 146



TABLE OF CONTENTS

CHAPTER-4: ANTICIPATED ENVIRONMENTAL IMPACTS & MITIGATION MEASURES

4.1 Introduction 148

4.2 Impact Assessment and Mitigation Measures 149

4.2.1 Air Environment 151

4.2.1.1 Potential Impacts 151

4.2.1.2 Fugitive Emissions 151

4.2.1.3 Air Pollution Modelling 152

4.2.1.4 Model Input Data 152

4.2.1.5 Presentation of Results 153

4.2.1.6 Mitigation measures 157

4.2.2 Noise Environment 157

4.2.2.1 Noise from the drilling rig 157

4.2.2.2 Mathematical model for sound wave propagation during operation 158

4.2.2.3 Input for the Model 158

4.2.2.4 Presentation of Results 159

4.2.2.5 Occupational Health Hazards from noise pollution 159

4.2.2.6 Community Noise Level 160

4.2.2.7 Noise emanated by Machineries and Equipment 160

4.2.2.8 Noise from Vehicular Traffic 161

4.2.2.9 Noise Control Measures 161

4.2.3 Water Environment 161

4.2.3.1 Sources of water Pollution 161

4.2.3.2 Potential surface and ground water impacts 162

4.2.3.3 Impact to surface water quality 162

4.2.3.4 Impact on ground water regime 163



TABLE OF CONTENTS

4.2.4 Topography and Climate 164

4.2.4.1 Impact on Topography 164

4.2.4.2 Impact on Climate 164

4.2.5 Land Environment 164

4.2.5.1 Land required for drilling activity 165

4.2.5.2 Impact on soil quality 165

4.2.5.3 Soil Contamination 165

4.2.5.4 Localized Alteration of subsoil and overland drainage pattern 165

4.2.5.5 Alteration of soil quality by loss of topsoil 165

4.2.6 Biological Environment 166

4.2.6.1 Impact on Terrestrial Environment 167

4.2.6.2 Impact on Aquatic Environment 167

4.2.7 Socio-Economic Environment 168

4.2.7.1 Impact on civic amenities 169

4.2.7.2 Impact on health 169

4.2.7.3 Impact on social well being 169

4.2.7.4 Impact due to vehicular movement 169

4.2.7.5 Other impacts on resources and infrastructure 170

4.2.8 Environment Management Plan 170

4.2.8.1 Atmospheric Emissions 170

4.2.8.2 Noise Environment 171

4.2.8.3 Soil Erosion 171

4.2.8.4 Land Environment 171

4.2.8.5 Water Environment 171

4.2.8.6 Biological Environment 171

4.2.8.7 Socio-economic Environment 171

4.2.9 Environmental Measures during well construction 173



TABLE OF CONTENTS

4.2.9.1 Management of Drilling Wastes 174

4.2.9.2 Management of Solid Wastes 175

4.2.9.3 Management of Discharge of aqueous Effluents 176

4.2.9.4 Management of waste disposal sites within drill site 176

4.2.10 Drilling Program Safety Guidelines 177

4.2.11 Monitoring Environmental Performance 177

4.2.12 Drilling Site Restoration Plan 177

4.2.13 Decommissioning upon abandonment 178

4.2.14 Occupational Health Surveillance Program 178

CHAPTER-5 ANALYSIS OF ALTERNATIVES (TECHNOLOGY & SITE)

5.1 Alternatives for Project Site 184

5.2 Alternatives for Technology 184

CHAPTER-6 ENVIRONMENTAL MONITORING PROGRAM

6.1 Environmental Monitoring and Reporting Procedure 186

6.2 Reporting Schedules Of The Monitoring Data 196

6.3 Infrastructure for Monitoring of Environmental Protection Measures 196

6.3.1 Air Quality and Meteorology 196

6.3.2 Water and waste water quality 197

6.3. Noise levels 198

6.4 Audit and Review 198

CHAPTER-7: ADDITIONAL STUDIES

7.1 Risk Assessment 201

7.1.1 Approach to the Study 201

7.1.2 Maximum Credible Accident Analysis (MCAA) 201



TABLE OF CONTENTS

7.1.3 Damage Effects of Various Heat Loads 206

7.1.4 Scenario Identification 207

7.1.5 Input Data for Consequence Analysis 207

7.1.6 Results and Discussion 209

7.1.7 Failure Frequency Analysis 209

7.1.8 Historical Data Sources 209

7.1.9 Probability of Immediate Ignition and Individual Risk Assessment Criteria 210

7.1.10 Individual Risk Assessment 210

7.1.11 Geo Hazards 211

7.2 Recommendations to mitigate blow out Risk / Hazards 211

7.3 Disaster Management Plan 212

7.3.1 Objectives of Disaster Management Plan 212

7.3.2 Different Phases of Disaster 213

7.3.2.1 Warning Phase 213

7.3.2.2 Period of Impact Phase 214

7.3.2.3 Rescue Phase 214

7.3.2.4 Relief Phase 215

7.3.2.5 Rehabilitation Phase 215

7.3.3 Key Elements of DMP 215

7.3.3.1 Basis of the Plan 215

7.3.3.2 Onsite Disaster Management Plan Purpose 215

7.3.3.3 Offsite Disaster Management Plan Purpose 216

7.3.4 Level of Emergencies 217

7.3.4.1 Minor Emergency 218

7.3.4.2 Major Emergency 219

7.3.5 Overall Philosophy of Emergency Response 220

7.3.6 Auditing 220



TABLE OF CONTENTS

7.3.7 Emergency Priorities 220

7.3.8 Emergency Response Management Group Interfaces 221

7.3.9 Emergency Response Procedure 221

7.3.9.1 Minor Emergency 221

7.3.9.2 Major Emergency 221

7.3.9.3 Emergency Response Strategies 223

7.3.10 Alert Phase 224

7.3.11 Preparedness for Emergencies 224

7.3.12 Control of Emergencies 225

7.4 Emergency Response Action 225

7.5 Emergency Response Procedures 226

7.5.1 Blow Out 226

7.5.2 Well Control 229

7.5.3 Hydrogen Sulphide 230

7.5.4 Abandonment of Rig/well 231

7.5.5 Structural Damage/Failure of the Rig 232

7.5.6 Well Control Emergencies 233

7.5.7 Fire on Rig 234

7.5.8 Rig Evacuation 235

7.5.9 Gas Release on Rig 236

7.5.10 Structural Damage 237

7.5.11 Ground Movement 238

7.5.12 Un-Ignited Gas Release 239

7.5.13 Hydrocarbon Spill 240

7.5.14 Medical Evacuation 241

7.5.15 Criminal Acts 242

7.5.16 Bomb Threat/ Extortion 243



TABLE OF CONTENTS

7.6 End of Emergency 244

7.7 Communications 245

7.7.1 Communication Network 245

7.8 Occupational Health & Safety Management Plan 245

CHAPTER-8: PROJECT BENEFITS

8.0 Project Benefits 248

8.1 Improvements in the Physical Infrastructure 248

8.2 Improvements in the Social Infrastructure 248

8.3 Employment Potential Other Tangible Benefits 249

CHAPTER-9: ENVIRONMENTAL COST BENEFIT ANALYSIS

9.1 Project Cost 251

9.2 Capital and Recurring Cost 252

CHAPTER-10: ENVIRONMENT MANAGEMENT PLAN

10.1 Introduction 254

10.2 EMP during Various Project Phases 255

10.3 Environmental Policy of the Company 255

10.4 Organisation Structure-HSE 255

10.5 EMP Plan for the Proposed Project 255

10.6 Environment Protection and Reclamation Plan 256

10.7 Environment Management Plan 257

10.7.1 Air Environment 257

10.7.2 Noise Environment 258



TABLE OF CONTENTS

10.7.3 Water Environment 258

10.7.4 Biological Environment 259

10.7.5 Land Environment 259

10.7.6 Soil Environment 260

10.7.7 Storage and Handling of Materials and Spills 260

10.7.8 Social Management Plan 261

Annexures

Annexure – I TOR

Annexure – II Corporate Environmental Policy

Annexure – III Air Monitoring Results

Annexure – IV Applicable Environmental Standards

List of Tables

Table No. Title Page No.

1.1 Brief description of project 09

1.2 Block Coordinates of 21 ML Blocks 10

1.3 Environmental Attributes and frequency of monitoring 16

2.1 Salient Features of the Proposed Project 24

2.2 Water Requirements for each well site 25

2.3 Details of DG sets 27

2.4 Constituents of Water Based Mud (WBM) 27

2.5 Special Additives and their Functions in water based mud 28

3.1 Land use Pattern of Mehsana 60

3.2 Summary Of The Meteorological Data Generated In Study Area 61

3.3 Summary Of Wind Pattern at Rupal 62

3.4 Weather Data From IMD, Ahmedabad (1971-2000) 65

3.5 Techniques Used For Ambient Air Quality Monitoring 68

3.6 Details Of Ambient Air Quality Monitoring Locations 69

3.7 Summary of Ambient Air Quality Monitoring Results 72

3.8 Noise Level Monitoring of Locations 78

3.9 Ground Water Sampling Locations 86

3.10 Surface Water Sampling Locations 86

3.11(a) Ground water Analysis Results 89

3.11 (b) Ground water Analysis Results 92

3.12 (a) Surface Water Analysis Results 95



TABLE OF CONTENTS

3.12 (b) Surface Water Analysis Results 99

3.12 (c) Surface Water Analysis Results 102

3.13 Soil Analysis Locations 110

3.14 (a) Soil Analysis Results 111

3.14 (b) Soil Analysis Results 113

3.15 List of Flora recorded in Block Area 117

3.16 List of Fauna around the Project Area 124

3.17 List Of Phytoplankton Species Identified From Study Area 131

3.18 List Of Zooplankton Species Identified From Study Area 131

3.19 Details Of Aquatic Sampling Locations 131

4.1 Key Potential Impacts Of Exploration Activities 148

4.2 Impact Significance Criteria 149

4.3 Activities – Impacts/Risks Interaction Environmental Sensitivities 150

4.4 Details Of DG Sets 152

4.5 Emission Characteristics- Model Inputs 153

4.6 Predicted 24 Hourly Short Term Incremental Concentrations 156

4.7 Resultant Concentrations due to INCREMENTAL GLC's 156

4.8 Input Data for Noise Modelling 159

4.9 Predicted Noise Levels 159

4.10 Noise Exposure Levels & its Effects 160

4.11 Summary Of Impact Assessment: Water Resources 163

4.12 Summary of Impact Assessment: Soil and Land Use 166

4.13 Summary of Impact Assessment Flora and Fauna 168

4.14 Prediction of Qualitative Impacts in Socio Economic Environment 172

4.15 Summary of Identified Impacts and Proposed Mitigation Measures 178

6.1 Schedule Of Environmental Monitoring 188

7.1 List Of Major Hazards 203

7.2 Occupational Hazards 203

7.3 Damage Due To Peak Over Pressure 206

7.4 Damage Due To Incident Radiation Intensities 206

7.5 Input Data For Consequence Analysis 208

7.6 Summary Of Consequence Analysis For Jet Fire Scenario At Well 209

7.7 Probability Of Ignition For Leaks Of Flammable Fluids 210

7.8 The Adnoc Individual Risk Assessment Criteria 210

7.9 Recommendations To Mitigate Blow Out Risk/Hazards 211

7.10 Emergency Operation Taskforce Functions 216

9.1 Project Cost 251

9.2 Capital and Recurring Cost for Pollution Control Measures 252

10.1 Summary Of Environmental Management Actions 264



TABLE OF CONTENTS

List of Figures

Figure No.

Title Page No.

1.1 Index Map of the area 5

1.2 Topographic Map Of Block Locations In Sivsagar District 6

2.1 Water Balance of each well site 26

2.2 Drilling Rig Sketch 31

2.3 Drilling Fluid Circulation System At Typical Rig 39

2.4 Typical Section View Of Drilling Cut And Drill Mud Collection Pit 46

3.1 Hydrogeology Map of District 53

3.2 Ground Water Pre Monsoon Level map of Mehsana District 55

3.3 Ground Water Post Monsoon Level map of Mehsana District 56

3.4 Seismic Zone Map of India 57

3.5 Seismic Zone-III of Study Area 57

3.6 Land Use Pattern Of Study Area 59

3.7(a) Windrose Diagram For April-18, May -18, June 18 & July 18 At Rupal 62

3.7 (b) Windrose Diagram For April-18, May -18, June 18 & July 18 At Rupal 63

3.8(a) Windrose Diagrams For The Month Of April, May, June & July - IMD, Ahmedabad(1971- 2000)

64

3.8 (b) Windrose Diagrams For The Month Of April, May, June & July - IMD, Ahmedabad (1971- 2000)

65

3.9 Monthly average Maximum & Minimum Temperature in ºC 66

3.10 Monthly average rainfall in mm & Relative humidity in % 66

3.11 Map Showing AAQ Monitoring Stations 70

3.12 Photographs Of Ambient Air Quality Monitoring Locations 71

3.13 Variation of Particulate Matter PM10 in the study area 74

3.14 Variation of Particulate Matter PM2.5 in the study area 74

3.15 Variation of Sulphur di oxide (SO2) in the study area 75

3.16 Variation of Oxides of Nitrogen (NOx) in the study area 75

3.17 Map Showing Noise Monitoring Stations 77

3.18 Noise Quality Monitoring At Various Locations 83

3.19 Map Showing Ground And Surface Water Monitoring Stations 87

3.20 Photographs Of Ground Water Monitoring 108

3.21 Photographs Of Surface Water Monitoring 109

3.22 Maps showing Monitoring Locations 111

3.23 Particle Size Distribution 114

3.24 Soil Sampling Location 115



TABLE OF CONTENTS

3.25 Sampling of Study Area 119

3.26 Vegetation of Study Area 120

3.27 Mushrooms found in the study area 121

3.28 Birds found in the study area 123

3.29 Nilgai found in the Agricultural field of study area 126

3.30 Tortoises found in the pond of study area 127

3.31 Indian star tortoises found in the study area 127

3.32 Aquatic Sampling Location of the study area 129

3.33 Shannon Diversity Index of Planktons 133

3.34 Distribution of population in the study area 136

3.35 Population density 137

3.36 Literacy level of the population in the study area 137

3.37 Distribution of Population by Social structure 139 3.38 Occupational Structure of the population 139 3.39 Socioeconomic Survey of the study area 143 3.40 Animal Husbandry of study area 145 7.3 Flowchart For Evaluation Of Consequences During The Release Of

Flammable Or Toxic Chemical 208

7.4 DMP Process Flow Diagram 214 7.5 Organizational Setup For The On-Site DMP 218 7.6 Organizational Setup For The Off-Site DMP 219 7.7 Emergency Classification 222 7.8 Contingency Plan For Onshore Blowout (Drilling Rig) 228 7.9 Typical Schematic Of Bop Stack 231 10.1 Plants Which Counteract Air Pollution (Odour Of Sulphur) 263

Onshore Oil & Gas Exploration of 46 wells in 12 ML Blocks of Western Onshore Basin ,

Doc. No. ONGC/CHSE/EIA/WOB/2018-19/01

Rev. No. 02



Rev. No. 02

Issue date 08/01/2019

Chapter No. Abbreviations & Glossary

i

ABBREVIATIONS

BLEVE Boiling Liquid Evaporating Vapour Explosion

BOD Biological Oxygen Demand

BOP Blow-out Preventer

CAGR Compounded Annual Growth Rate

CC&A Common Consent and Authorization (Consent to Operate (for water and air emissions) and Authorization (for management of hazardous wastes)

CGWA Central Ground Water Authority

COD Chemical Oxygen Demand

CPCB Central Pollution Control Board

DG Diesel Generator

DGH Directorate General of Hydrocarbons

DMP Disaster Management Plan

EC Environmental Clearance

ECC Emergency Control Centre

EHS Environmental Health and Safety

EIA Environmental Impact Assessment

EMP Environmental Management Plan

EOR Enhanced oil Recovery

FAE Functional Area Expert

GGS Group Gathering Stations

GLC Ground Level Concentration

GoI Government of India

GPCB Gujarat Pollution Control Board

HAZOP Hazard and Operability Study

HDPE High Density Polyethylene

HSD High Speed Diesel

HSE Health, Safety and Environment

IMD Indian Meteorological Department

INR Indian Rupees

KLD Kilo Litre per Day

LU Land Use

ML Mining Lease

MoEF Ministry of Environment and Forest

MSDS Material Safety Data Sheet

MSL Mean Sea Level

MT Metric Tonnes

NABET National Accreditation Board for Education and Training

NDT Non Destructive Testing

NMHC Non-Methane Hydrocarbons

NOC No-Object Certificates (Consent to Establish)

NOx Nitrogen Oxides

OOIP original oil in-place

ONGC Oil and Natural Gas Corporation Limited



Rev. No. 02



ii

OMR Oil Mines Regulation

PDCR Plan, Do, Check and Review

PEL Petroleum Exploration License

PM Particulate Matter

PPE Personal Protective Equipment

PSC Production Sharing Contract

SAR Sodium Absorption Ratio

SO2 Sulphur Dioxide

TDS Total Dissolved Solids

TSDF Treatment, Storage, and Disposal Facility

USEPA United States Environment Protection Agency

VOCs Volatile Organic Compounds



Rev. No. 02



iii

GLOSSARY

ABANDONED WELL: A dry hole in which no producible oil or gas was present, or a well that has stopped

producing. Abandoned wells must be plugged to prevent seepage of oil, gas, or water from one formation

to another.

ACCIDENT: An accident may be defined as ’an undesirable and unplanned event with or without or major

or minor damage consequence to life and/or property.’

ACTIVE WELL: A well in mechanical condition for production or service use (i.e., in active production or

service use).

API: It is the short form of American Petroleum Institute. It is the oil industry’s trade organization. API’s

research and engineering work provides a basis for establishing operating and safety standard issues;

specifications for the manufacturing of oil field equipment; and furnishes statistical and other information

to related agencies.

ASSOCIATED GAS: Gas combined with oil or dissolved in crude oil. Known also as cap gas and solution

gas, it provides the drive mechanism needed to force oil to the surface of a well. Associated gas is

normally present in an oil reservoir in the early stages of production.

BARREL: The standard unit of measure of liquids in the petroleum industry. It is equivalent to 42 U.S.

standard gallons or 159 litres of oil.

BARREL OF OIL EQUIVALENT (BOE): The amount of energy resource that is equal to one barrel of oil

on an energy basis. The conversion is based on the assumption that one barrel of oil produces the same

amount of energy when burned as 5,620 cubic feet of natural gas.

BASIN: A depression of the earth’s surface into which sediments are deposited, usually characterized

by sediment accumulation over a long interval; a broad area of the earth beneath which layers of rock

are inclined, usually from the sides toward the centre.

BED: A layer of rock, usually sediments, which is homogeneous (the same) in composition. One bed is

separated from another by a bedding plane.



Rev. No. 02



iv

BID: An offer for a lease submitted by a potential lessee in the form of a cash bonus dollar amount or

other commitments as specified in the final notice of sale.

BLEVE: (BOILING LIQUID EXPANDING VAPOUR EXPLOSION): This is a type of explosion that can

occur when a vessel containing a pressurized liquid is ruptured. Such explosions can be extremely

hazardous.

BLOWOUT: An uncontrolled flow of gas, oil, or other fluids from a well to the atmosphere. A well may

blow out when formation pressure exceeds the pressure overburden of a column of drilling fluid.

BLOWOUT PREVENTER: A special assembly of heavy-duty valves, commonly called the BOP stack,

installed on top of a well which can be closed to prevent high-pressure oil or gas from escaping (a

blowout) from the well hole during drilling operations.

BOREHOLE: The hole in the earth made by the drill; the uncased drill hole from the surface to the bottom

of the well.

CASING: Steel pipe used in oil wells to seal off fluids in the rocks from the bore hole and to prevent the

walls of the hole from caving.

CASING HEAD: The top of the casing set in a well; the part of the casing that protrudes above the surface

and to which the control valves and flow pipes are attached.

CASING HEAD GAS: Gas produced from an oil well as distinguished from gas from a gas well. The

casing head gas is taken off at the top of the well or at the separator.

COMMERCIAL WELL: A well of sufficient net production that it could be expected to pay out in a

reasonable time and yield a profit from the operation.

COMPLETED WELL: A well that has been mechanically completed for production or service use. There

may be more than one completed zone in the well.

CONDENSATE: A natural gas with a low vapour pressure compared with natural gasoline and liquefied

petroleum gas. It is produced from a deep well where the temperature and pressure are high. Gas



Rev. No. 02



v

condenses as it rises up the well bore and reaches the surface as condensate. Similarly, condensate

separates out naturally in pipelines or in a separation plant by the normal process of condensation.

DEVELOPMENT: Activities following exploration including the installation of facilities and the drilling and

completion of wells for production purposes.

DIRECTIONAL DRILLING: The technique of drilling at an angle from the vertical by deflecting the drill

bit. Directional wells are drilled to develop an offshore lease from one drilling platform; to reach a pay

zone where drilling cannot be done, such as beneath a shipping lane.

DISASTER: Is a catastrophic consequence of a major emergency/accident that leads to, not only

extensive damage to life and property but also disrupts all normal human activity for a long time and

requires a major national and international effort for rescue and rehabilitation of those affected.

DISCOVERY: A find of significant quantity of gas or oil.

DRILL CUTTINGS: Chips and small fragments of drilled rock that are brought to the surface by the flow

of the drilling mud as it is circulated.

DRILL PIPE: Heavy, thick walled, hollow steel pipe used in rotary drilling to turn the drill bit and to provide

a conduit for the drilling mud.

DRILLING CONTRACTOR: A person or company whose business is drilling wells. Wells are drilled on

several contract specifications: per foot, day rate, or turnkey (that is, upon completion). Most major oil

companies do not own drilling rigs. Exploration and development drilling is contracted. Personnel

manning the rigs work for the contractor.

DRILLING MUD: A special mixture of clay, water, or refined oil, and chemical additives pumped down

through the drill pipe and drill bit. The mud cools the rapidly rotating bit; lubricates the drill pipe as it turns

in the well bore; carries rock cuttings to the surface; serves as a plaster to prevent the wall of the borehole

from crumbling or collapsing; and provides the weight or hydrostatic head to prevent extraneous fluids

from entering the well bore and to control down hole pressures that may be encountered.

DRY HOLE: A well drilled to a certain depth without finding commercially exploitable hydrocarbons.



Rev. No. 02



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DRY GAS: Natural gas from the well that is free of liquid hydrocarbons; gas that has been treated to

remove all liquids; pipeline gas.

EMERGENCY: Is a situation of process deviation that if uncontrolled may lead to a major

accident/disaster with potential short term and/or long term risk damage consequence to life and property

in and/or around the facility.

ENVIRONMENTAL IMPACT ASSESSMENT: A statement required under the Environmental Impact

Assessment Notification, 2006 or similar regulations by other bodies in relation to any action significantly

affecting the environment, including certain exploration and drilling activities.

EXPLORATION: The process of searching for minerals preliminary to development. Exploration activities

include (1) geophysical surveys, (2) drilling to locate an oil or gas reservoir, and (3) the drilling of additional

wells after a discovery to delineate a reservoir. It enables the lessee to determine whether to proceed

with development and production.

EXPLOSION: An explosion is a sudden increase in volume and release of energy in an extreme manner,

usually with the generation of high temperatures and the release of gases.

FIELD: A geographical area in which one or more oil or gas wells produce. A field may refer to surface

area only or to underground productive formation. A single field may include several reservoirs separated

either horizontally or vertically.

FIREBALL: The burning of a flammable gas cloud on being immediately ignited at the edge before

forming a flammable/explosive mixture.

FLAMMABLE LIMIT: Flammable limits refer to the conditions under which a mixture of a flammable

material and air may catch fire or explode. When vapour s of a flammable or combustible liquid are mixed

with air in the proper proportions in the presence of a source of ignition, rapid combustion or an explosion

can occur. The proper proportion is called the flammable range and is also often referred to as the

explosive range. The flammable range includes all concentrations of flammable vapour or gas in air, in

which a flash will occur or a flame will travel if the mixture is ignited.

FLASH FIRE: A flammable gas release getting ignited at the farthest edge resulting in flash-back fire.



Rev. No. 02



vii

Gas Lost: Natural gas which is flared or vented (i.e., natural gas not retained in the production system

for sale or use).

HAZARD: Is the potential of an Accident.

INCIDENT: Is an emergent situation of any critical deviation in the process control or otherwise that may

lead to a major accident/potential emergency and disaster.

LEASE: A legal document executed between a landowner (as lessor) and a company or individual (as

lessee) that conveys the right to exploit the premises for minerals or other products for a specified period

of time over a given area.

INJURY ZONE: Zone of injury in any hazardous event.

MAJOR ACCIDENT HAZARD (MAH) INDUSTRY: If the quantity of any chemical as listed in MSIHC

Rules’ Schedule-2 or Schedule-3 is equal to or greater than the Threshold Quantity given therein.

MAJOR ACCIDENT: Loss of life or 10 or more injuries on-site or 1 or more injuries off-site (as defined in

MSIHC Rules).

OIL LOST: Oil that is spilled or burned (i.e., oil not retained in the production system for sale).

OPERATOR: The individual, partnership, firm, or corporation having control or management of

operations on a leased area or a portion thereof. The operator may be a lessee, designated agent of the

lessee, holder of rights under an approved operation agreement, or an agent of an operating rights holder.

PLUGGED AND ABANDONED: Wells in which casings have been removed, and the well bore sealed

with mechanical or cement plugs.

PLUMES: Plumes are continuous release of hazardous gases and vapours. Smoke from a chimney is

an example. Plumes can cause Fires and Explosions as secondary scenarios, in case the gases are

flammable & ignition occurs.

PRODUCIBLE LEASE: A lease where one well or several wells have discovered hydrocarbons in paying

quantities, but for which there is no production during the reporting period.



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viii

PRODUCIBLE ZONE COMPLETION: The interval in a well bore that has been mechanically prepared

to produce oil, gas or sulphur. There can be more than one zone completed for production in a well bore.

PRODUCING LEASE: A lease that is producing oil, gas, or sulphur in quantities sufficient to generate

royalties.

PRODUCTION: The phase of oil and gas operations involved with well fluids extraction, separation,

treatment, measurement, etc.

PROVEN RESERVES (SOCIETY OF PETROLEUM ENGINEERS): Reserves that can be estimated with

reasonable certainty to be recovered under current economic conditions. Current economic conditions

include processing costs prevailing at the time of the estimate. Proved reserves must either have facilities

that are operational at the time of the estimate to process and transport those reserves to market, or a

commitment of reasonable expectation to install such facilities in the future. Proved reserves can be

subdivided into undeveloped and developed Reserves.

PUFFS: Puffs are instantaneous release of hazardous gases and vapours. Puffs can give rise to FIRE

BALLS and vapour cloud explosions (VCE). A special case of vapour cloud explosion is the Boiling Liquid

Evaporating Vapour Explosion (BLEVE).

RENT: Periodic payments made by the holder of a lease, during the primary lease term for the right to

use the land or resources for purposes established in the lease.

ROYALTY: Payment, in value (money) or in kind, of a stated proportionate interest in production from

mineral deposits by the lessees to the Government.

SALES VALUE: The proceeds received for the sale of the mineral.

SERVICE ZONE COMPLETION: The interval in a well bore that has been mechanically prepared for

service use, usually water or gas injection to stimulate production from other wells or for water or other

waste disposal.

SESMIC SURVEY: The seismic survey is one form of geophysical survey that aims at measuring the

earth’s (geo-) properties by means of physical (-physics) principles such as magnetic, electric,

gravitational, thermal, and elastic theories



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ix

SPILLS: Spills are liquid pools created by leaking liquid chemicals. Spills may cause evaporation and

dispersal of toxic gases and if the spilled liquid is flammable, then it can catch fire creating a pool fire, or

the vapour can cause explosion.

SUSPENDED WELL: A well on which operations have been discontinued. The usual context is an

uncompleted well in which operations ceased during drilling but which has not been plugged and

abandoned permanently.

UPPER EXPLOSIVE LIMIT (UEL)/ UPPER FLAMMABILE LIMIT (UFL): Upper flammable limit (UEL) or

the upper explosive limit is the maximum concentration of vapour or gas in air below which propagation

of flame does not occur on contact with a source of ignition. The mixture is said to be too rich.

LOWER EXPLOSIVE LIMIT (LEL)/ LOWER FLAMMABILE LIMIT (LFL): Lower flammable limit (LEL)

or the lower explosive limit is the minimum concentration of vapour or gas in air above which propagation

of flame does not occur on contact with a source of ignition. The mixture is said to be too lean.

VCE: (VAPOUR CLOUD EXPLOSION); Explosion resulting from vapour clouds formed from flashing

liquids or non-flashing liquids and gases. Sometimes also referred to as unconfined vapour cloud

explosion.

VULNERABILITY ZONE: Zone of Exposure leading to Fatality or recoverable injury in any hazardous

event.

WELL: A hole drilled or bored into the earth, usually cased with metal pipe, for the production of gas or

oil. A hole for the injection under pressure of water or gas into a subsurface rock formation.



Rev. No. 02



i

ABBREVIATIONS

BLEVE Boiling Liquid Evaporating Vapour Explosion

BOD Biological Oxygen Demand

BOP Blow-out Preventer

CAGR Compounded Annual Growth Rate

CC&A Common Consent and Authorization (Consent to Operate (for water and air emissions) and Authorization (for management of hazardous wastes)

CGWA Central Ground Water Authority

COD Chemical Oxygen Demand

CPCB Central Pollution Control Board

DG Diesel Generator

DGH Directorate General of Hydrocarbons

DMP Disaster Management Plan

EC Environmental Clearance

ECC Emergency Control Centre

EHS Environmental Health and Safety

EIA Environmental Impact Assessment

EMP Environmental Management Plan

EOR Enhanced oil Recovery

FAE Functional Area Expert

GGS Group Gathering Stations

GLC Ground Level Concentration

GoI Government of India

GPCB Gujarat Pollution Control Board

HAZOP Hazard and Operability Study

HDPE High Density Polyethylene

HSD High Speed Diesel

HSE Health, Safety and Environment

IMD Indian Meteorological Department

INR Indian Rupees

KLD Kilo Litre per Day

LU Land Use

ML Mining Lease

MoEF Ministry of Environment and Forest

MSDS Material Safety Data Sheet

MSL Mean Sea Level

MT Metric Tonnes

NABET National Accreditation Board for Education and Training

NDT Non Destructive Testing

NMHC Non-Methane Hydrocarbons

NOC No-Object Certificates (Consent to Establish)

NOx Nitrogen Oxides

OOIP original oil in-place

ONGC Oil and Natural Gas Corporation Limited



Rev. No. 02



ii

OMR Oil Mines Regulation

PDCR Plan, Do, Check and Review

PEL Petroleum Exploration License

PM Particulate Matter

PPE Personal Protective Equipment

PSC Production Sharing Contract

SAR Sodium Absorption Ratio

SO2 Sulphur Dioxide

TDS Total Dissolved Solids

TSDF Treatment, Storage, and Disposal Facility

USEPA United States Environment Protection Agency

VOCs Volatile Organic Compounds



Rev. No. 02



iii

GLOSSARY

ABANDONED WELL: A dry hole in which no producible oil or gas was present, or a well that has stopped

producing. Abandoned wells must be plugged to prevent seepage of oil, gas, or water from one formation

to another.

ACCIDENT: An accident may be defined as ’an undesirable and unplanned event with or without or major

or minor damage consequence to life and/or property.’

ACTIVE WELL: A well in mechanical condition for production or service use (i.e., in active production or

service use).

API: It is the short form of American Petroleum Institute. It is the oil industry’s trade organization. API’s

research and engineering work provides a basis for establishing operating and safety standard issues;

specifications for the manufacturing of oil field equipment; and furnishes statistical and other information

to related agencies.

ASSOCIATED GAS: Gas combined with oil or dissolved in crude oil. Known also as cap gas and solution

gas, it provides the drive mechanism needed to force oil to the surface of a well. Associated gas is

normally present in an oil reservoir in the early stages of production.

BARREL: The standard unit of measure of liquids in the petroleum industry. It is equivalent to 42 U.S.

standard gallons or 159 litres of oil.

BARREL OF OIL EQUIVALENT (BOE): The amount of energy resource that is equal to one barrel of oil

on an energy basis. The conversion is based on the assumption that one barrel of oil produces the same

amount of energy when burned as 5,620 cubic feet of natural gas.

BASIN: A depression of the earth’s surface into which sediments are deposited, usually characterized

by sediment accumulation over a long interval; a broad area of the earth beneath which layers of rock

are inclined, usually from the sides toward the centre.

BED: A layer of rock, usually sediments, which is homogeneous (the same) in composition. One bed is

separated from another by a bedding plane.



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iv

BID: An offer for a lease submitted by a potential lessee in the form of a cash bonus dollar amount or

other commitments as specified in the final notice of sale.

BLEVE: (BOILING LIQUID EXPANDING VAPOUR EXPLOSION): This is a type of explosion that can

occur when a vessel containing a pressurized liquid is ruptured. Such explosions can be extremely

hazardous.

BLOWOUT: An uncontrolled flow of gas, oil, or other fluids from a well to the atmosphere. A well may

blow out when formation pressure exceeds the pressure overburden of a column of drilling fluid.

BLOWOUT PREVENTER: A special assembly of heavy-duty valves, commonly called the BOP stack,

installed on top of a well which can be closed to prevent high-pressure oil or gas from escaping (a

blowout) from the well hole during drilling operations.

BOREHOLE: The hole in the earth made by the drill; the uncased drill hole from the surface to the bottom

of the well.

CASING: Steel pipe used in oil wells to seal off fluids in the rocks from the bore hole and to prevent the

walls of the hole from caving.

CASING HEAD: The top of the casing set in a well; the part of the casing that protrudes above the surface

and to which the control valves and flow pipes are attached.

CASING HEAD GAS: Gas produced from an oil well as distinguished from gas from a gas well. The

casing head gas is taken off at the top of the well or at the separator.

COMMERCIAL WELL: A well of sufficient net production that it could be expected to pay out in a

reasonable time and yield a profit from the operation.

COMPLETED WELL: A well that has been mechanically completed for production or service use. There

may be more than one completed zone in the well.

CONDENSATE: A natural gas with a low vapour pressure compared with natural gasoline and liquefied

petroleum gas. It is produced from a deep well where the temperature and pressure are high. Gas



Rev. No. 02



v

condenses as it rises up the well bore and reaches the surface as condensate. Similarly, condensate

separates out naturally in pipelines or in a separation plant by the normal process of condensation.

DEVELOPMENT: Activities following exploration including the installation of facilities and the drilling and

completion of wells for production purposes.

DIRECTIONAL DRILLING: The technique of drilling at an angle from the vertical by deflecting the drill

bit. Directional wells are drilled to develop an offshore lease from one drilling platform; to reach a pay

zone where drilling cannot be done, such as beneath a shipping lane.

DISASTER: Is a catastrophic consequence of a major emergency/accident that leads to, not only

extensive damage to life and property but also disrupts all normal human activity for a long time and

requires a major national and international effort for rescue and rehabilitation of those affected.

DISCOVERY: A find of significant quantity of gas or oil.

DRILL CUTTINGS: Chips and small fragments of drilled rock that are brought to the surface by the flow

of the drilling mud as it is circulated.

DRILL PIPE: Heavy, thick walled, hollow steel pipe used in rotary drilling to turn the drill bit and to provide

a conduit for the drilling mud.

DRILLING CONTRACTOR: A person or company whose business is drilling wells. Wells are drilled on

several contract specifications: per foot, day rate, or turnkey (that is, upon completion). Most major oil

companies do not own drilling rigs. Exploration and development drilling is contracted. Personnel

manning the rigs work for the contractor.

DRILLING MUD: A special mixture of clay, water, or refined oil, and chemical additives pumped down

through the drill pipe and drill bit. The mud cools the rapidly rotating bit; lubricates the drill pipe as it turns

in the well bore; carries rock cuttings to the surface; serves as a plaster to prevent the wall of the borehole

from crumbling or collapsing; and provides the weight or hydrostatic head to prevent extraneous fluids

from entering the well bore and to control down hole pressures that may be encountered.

DRY HOLE: A well drilled to a certain depth without finding commercially exploitable hydrocarbons.



Rev. No. 02



vi

DRY GAS: Natural gas from the well that is free of liquid hydrocarbons; gas that has been treated to

remove all liquids; pipeline gas.

EMERGENCY: Is a situation of process deviation that if uncontrolled may lead to a major

accident/disaster with potential short term and/or long term risk damage consequence to life and property

in and/or around the facility.

ENVIRONMENTAL IMPACT ASSESSMENT: A statement required under the Environmental Impact

Assessment Notification, 2006 or similar regulations by other bodies in relation to any action significantly

affecting the environment, including certain exploration and drilling activities.

EXPLORATION: The process of searching for minerals preliminary to development. Exploration activities

include (1) geophysical surveys, (2) drilling to locate an oil or gas reservoir, and (3) the drilling of additional

wells after a discovery to delineate a reservoir. It enables the lessee to determine whether to proceed

with development and production.

EXPLOSION: An explosion is a sudden increase in volume and release of energy in an extreme manner,

usually with the generation of high temperatures and the release of gases.

FIELD: A geographical area in which one or more oil or gas wells produce. A field may refer to surface

area only or to underground productive formation. A single field may include several reservoirs separated

either horizontally or vertically.

FIREBALL: The burning of a flammable gas cloud on being immediately ignited at the edge before

forming a flammable/explosive mixture.

FLAMMABLE LIMIT: Flammable limits refer to the conditions under which a mixture of a flammable

material and air may catch fire or explode. When vapour s of a flammable or combustible liquid are mixed

with air in the proper proportions in the presence of a source of ignition, rapid combustion or an explosion

can occur. The proper proportion is called the flammable range and is also often referred to as the

explosive range. The flammable range includes all concentrations of flammable vapour or gas in air, in

which a flash will occur or a flame will travel if the mixture is ignited.

FLASH FIRE: A flammable gas release getting ignited at the farthest edge resulting in flash-back fire.



Rev. No. 02



vii

Gas Lost: Natural gas which is flared or vented (i.e., natural gas not retained in the production system

for sale or use).

HAZARD: Is the potential of an Accident.

INCIDENT: Is an emergent situation of any critical deviation in the process control or otherwise that may

lead to a major accident/potential emergency and disaster.

LEASE: A legal document executed between a landowner (as lessor) and a company or individual (as

lessee) that conveys the right to exploit the premises for minerals or other products for a specified period

of time over a given area.

INJURY ZONE: Zone of injury in any hazardous event.

MAJOR ACCIDENT HAZARD (MAH) INDUSTRY: If the quantity of any chemical as listed in MSIHC

Rules’ Schedule-2 or Schedule-3 is equal to or greater than the Threshold Quantity given therein.

MAJOR ACCIDENT: Loss of life or 10 or more injuries on-site or 1 or more injuries off-site (as defined in

MSIHC Rules).

OIL LOST: Oil that is spilled or burned (i.e., oil not retained in the production system for sale).

OPERATOR: The individual, partnership, firm, or corporation having control or management of

operations on a leased area or a portion thereof. The operator may be a lessee, designated agent of the

lessee, holder of rights under an approved operation agreement, or an agent of an operating rights holder.

PLUGGED AND ABANDONED: Wells in which casings have been removed, and the well bore sealed

with mechanical or cement plugs.

PLUMES: Plumes are continuous release of hazardous gases and vapours. Smoke from a chimney is

an example. Plumes can cause Fires and Explosions as secondary scenarios, in case the gases are

flammable & ignition occurs.

PRODUCIBLE LEASE: A lease where one well or several wells have discovered hydrocarbons in paying

quantities, but for which there is no production during the reporting period.



Rev. No. 02



viii

PRODUCIBLE ZONE COMPLETION: The interval in a well bore that has been mechanically prepared

to produce oil, gas or sulphur. There can be more than one zone completed for production in a well bore.

PRODUCING LEASE: A lease that is producing oil, gas, or sulphur in quantities sufficient to generate

royalties.

PRODUCTION: The phase of oil and gas operations involved with well fluids extraction, separation,

treatment, measurement, etc.

PROVEN RESERVES (SOCIETY OF PETROLEUM ENGINEERS): Reserves that can be estimated with

reasonable certainty to be recovered under current economic conditions. Current economic conditions

include processing costs prevailing at the time of the estimate. Proved reserves must either have facilities

that are operational at the time of the estimate to process and transport those reserves to market, or a

commitment of reasonable expectation to install such facilities in the future. Proved reserves can be

subdivided into undeveloped and developed Reserves.

PUFFS: Puffs are instantaneous release of hazardous gases and vapours. Puffs can give rise to FIRE

BALLS and vapour cloud explosions (VCE). A special case of vapour cloud explosion is the Boiling Liquid

Evaporating Vapour Explosion (BLEVE).

RENT: Periodic payments made by the holder of a lease, during the primary lease term for the right to

use the land or resources for purposes established in the lease.

ROYALTY: Payment, in value (money) or in kind, of a stated proportionate interest in production from

mineral deposits by the lessees to the Government.

SALES VALUE: The proceeds received for the sale of the mineral.

SERVICE ZONE COMPLETION: The interval in a well bore that has been mechanically prepared for

service use, usually water or gas injection to stimulate production from other wells or for water or other

waste disposal.

SESMIC SURVEY: The seismic survey is one form of geophysical survey that aims at measuring the

earth’s (geo-) properties by means of physical (-physics) principles such as magnetic, electric,

gravitational, thermal, and elastic theories



Rev. No. 02



ix

SPILLS: Spills are liquid pools created by leaking liquid chemicals. Spills may cause evaporation and

dispersal of toxic gases and if the spilled liquid is flammable, then it can catch fire creating a pool fire, or

the vapour can cause explosion.

SUSPENDED WELL: A well on which operations have been discontinued. The usual context is an

uncompleted well in which operations ceased during drilling but which has not been plugged and

abandoned permanently.

UPPER EXPLOSIVE LIMIT (UEL)/ UPPER FLAMMABILE LIMIT (UFL): Upper flammable limit (UEL) or

the upper explosive limit is the maximum concentration of vapour or gas in air below which propagation

of flame does not occur on contact with a source of ignition. The mixture is said to be too rich.

LOWER EXPLOSIVE LIMIT (LEL)/ LOWER FLAMMABILE LIMIT (LFL): Lower flammable limit (LEL)

or the lower explosive limit is the minimum concentration of vapour or gas in air above which propagation

of flame does not occur on contact with a source of ignition. The mixture is said to be too lean.

VCE: (VAPOUR CLOUD EXPLOSION); Explosion resulting from vapour clouds formed from flashing

liquids or non-flashing liquids and gases. Sometimes also referred to as unconfined vapour cloud

explosion.

VULNERABILITY ZONE: Zone of Exposure leading to Fatality or recoverable injury in any hazardous

event.

WELL: A hole drilled or bored into the earth, usually cased with metal pipe, for the production of gas or

oil. A hole for the injection under pressure of water or gas into a subsurface rock formation.

Onshore Oil & Gas Exploration of 46 Wells in 12 ML Blocks in Mehsana District of Gujarat


Rev. No. 02


Chapter No. ToR Compliance

x

Point wise compliance of TOR for the Onshore Oil & Gas Exploration of 46 wells in 12 ML blocks in Mehsana District, Gujarat. MoEF&CC No. IA-J-11011/158/2018-IA-II (I) dated 01/06/2018.

Sl. No Terms of Reference Status

1. Executive summary of a project.

Executive Summary has been enclosed given in EIA report.

2. Project description, project objectives and project benefits.

Project description is given in Chapter-2, project objectives are given in section-2.4 of Chapter-2 and benefits of the project are given in Chapter-8.

3.

Cost of Project and Period of completion

The total estimated cost of the proposed Project is 460 crores. The implementation schedule for the proposed project will be approximately 3-4 months from date of EC.

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.

Brief description of proposed Project is given in Table-1.1. The Topographic and Google map are shown in Figure-1.1 and Figure-1.2 of Chapter-1. Flora and fauna details are given in Section-3.11 of Chapter-3. land use pattern is given in Figure-3.6 of Chapter-3.

5. Details of sensitive areas such as National Park, Wildlife sanctuary and any other eco-sensitive area along with map indicating distance.

No Eco-senstive Zone found in the study area

6. Approval for the forest land from the State/Central Govt. under Forest (Conservation) Act, 1980, if applicable.

No Forest Area found in the Study Area

7. Recommendation of SCZMA/CRZ clearance as per CRZ Notification dated 6th January, 2011 ( if applicable).

Not Applicable

8. Distance from nearby critically/severely polluted area as per Notification, if applicable. Status of moratorium imposed on the area.

Nil

9. Does proposal involve rehabilitation and resettlement? If yes, details thereof

No

10.

Environmental considerations in the selection of the drilling locations for which environmental clearance is being sought.

Details are given in Section 2.4.2 of Chapter-2



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xi

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 center of Oil Field as its center covering the area of all proposed drilling wells.

The baseline studies were carried out from 27th April 2018 to 27th July 2018 representing Pre-monsoon Summer season. Details are given in Chapter-3 of EIA report.

12. Climatology and Meteorology including wind speed, wind direction, temperature rainfall relative humidity etc.

Climatology and Meteorological details are given in Section-3.6 of Chapter-3.

13. Details of Ambient Air Quality monitoring at 8 locations for PM2.5, PM10, SO2, NOx, CO, VOCs, Methane and non-methane HC.

Results of Ambient Air Quality monitoring are given in Section-3.8 of Chapter-3.

14. Soil sample analysis (physical and chemical properties) at the areas located at 5 locations.

Details of Soil Sampling analysis are given in Section-3.11 of Chapter-3.

15. Ground and surface water quality in the vicinity of the proposed wells site.

Surface water and ground water quality have been monitored and results are given in Section 3.10 of Chapter-3.

16. Measurement of Noise levels within 1 km radius of the proposed wells.

Noise level survey results are given in Section-3.9 of Chapter-3.

17. Vegetation and land use; flora/fauna in the block area with details of endangered species, if any

Details of flora and fauna are given in Section-3.12 of Chapter-3.

18. Incremental GLC as a result of DG set operation, flaring etc

Incremental GLC concentration results are mentioned in Section 4.2.1.3 of Chapter-4.

19. Potential environmental impact envisaged during various stages of project activities such as site activation, development, operation/ maintenance and decommissioning.

Impact assessment and mitigation measures for the stage wise proposed project activities are given in Chapter-4.

20. Actual source of water and 'Permission' for the drawl of water from the Competent Authority. Detailed water balance, wastewater generation and discharge.

The water requirement will be met from the local sources through ONGC Installations. Water requirement given in Section-2.5.1 of Chapter-2. Waste water generation details and mode of treatment are given in Section-2.5.3 of Chapter-2.

21. Noise abatement measures and measures to minimize disturbance due to light and visual intrusions.

Noise control measures are given in Section-4.2.2 of Chapter-4.

22. Details on wastewater generation, treatment and utilization /discharge for produced water/ formation water, cooling waters, other wastewaters, etc. during all project phases.

Wastewater generation details and mode of treatment are given in Section-2.5.3 of Chapter-2 and Section-4.2.9.3 of Chapter-4.



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xii

23. Details on solid waste management for drill cuttings, drilling mud and oil sludge, produced sand, radioactive materials, other hazardous materials, etc. including its disposal options during all project phases.

Solid waste management details are given in Section-4.2.9.2 of Chapter-4.

24. Disposal of spent oil and lube

Management of used oil details are given in Section-2.5.5 of Chapter-2.

25. Storage of chemicals and diesel at site. Hazardous material usage, storage and accounting.

Details for storage of chemicals are given in Section-2.5.1 of Chapter-2.

26. Commitment for the use of water based mud (WBM) only

Water Based Mud (WBM) waste from drilling details are given in Section-4.2.9 of Chapter-4.

27. Oil spill emergency plans for recovery/ reclamation.

Oil spill emergency plan is given in Section-7.6.13 of Chapter-7.

28. H2S emissions control.

H2S emission control details are given in Section-7.6.3 of Chapter-7.

29. Produced oil/gas handling, processing and storage/transportation.

Exploratory Drilling no production at this stage

30. Details of control of air, water and noise pollution during production phase.

Not applicable

31. Measures to protect ground water and shallow aquifers from contamination.

Mitigation Measures to protect ground water and surface water are given in Section-4.2.3.3 & Section-4.2.3.4 of Chapter-4.

32. Whether any burn pits being utilized for well test operations.

Nil

33. Risk assessment and disaster management plan for independent reviews of well-designed construction etc. for prevention of blow out. Blowout preventer installation.

Risk and disaster management plan details are given in Section-7.2 and Section-7.4 of Chapter-7. Blow out emergency Response procedure details are given in Section -7.6.1.

34. Environmental management plan EMP details are given in chapter-10

35. Total capital and recurring cost for environmental control measures.

The estimated cost of the proposed exploration well drilling is Rs.3500 crores. The cost for environmental control measures has been included in the total project cost.

36. Emergency preparedness plan.

Details are given in disaster management plan in section-7.6 of chapter-7.

37. Decommissioning and restoration plans.

Details of decommissioning and restoration plans section-2.5.9 of chapter-2.

38. Documentary proof of membership of common disposal facilities, if any

Membership of common disposal facilities is under progress.

39. Details of environmental and safety related documentation within the company including documentation and proposed occupational

Occupational health and safety details are mentioned in Section 7.9 of Chapter-7.



Rev. No. 02



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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.

Corporate Environment Policy of ONGC as shown in Annexure-II

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.

Nil

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1.0 EXECUTIVE SUMMARY

Oil and Natural Gas Corporation Limited (ONGC) proposes to carryout onshore Exploration of oil &

gas in 46 exploratory wells in 12 ML Blocks of Western Onshore basin in Mehsana District of Gujarat

state. As per the Environment Impact Assessment (EIA) Notification dated 14th September 2006, the

proposed project falls under ‘Category A’ of Activity Type 1(b) requires prior Environmental Clearance

(EC) to be obtained from MoEF&CC before the commencement of ground activity. The application for

prior EC (Form-1 and Pre-feasibility Report) for the Exploration of oil and gas in 46 wells (Onshore) of 12

ML Blocks of Western Onshore Basin has been submitted to MoEF&CC on 25th April 2018 and Terms of

Reference (TOR) has been issued by MoEF&CC vide letter reference F. No. IA-J-11011/158/2018-IA-II

(I) and Proposal No. IA/GJ/IND2/74678/2018 dated 1st June 2018.

1.1 Details of the Project

ONGC proposes onshore Exploration of oil & gas in 12 blocks in Mehsana District, Gujarat. The salient

features of the project are given in Table 1. The blocks details are given in Table-2

Table 1: Salient Features of the project

S.No. Particulars Details 1. Name of Blocks Jotana ML-; Linch ML; Linch Ext – I ML ;

Nandasan Langnaj ML ; North Shobhasan Ext – I ML ; Jotana – Warason ML; Kadi ML ;Linch Ext – II ML; Mansa ML; Jakasana ML; East Shobhasan ML ; and Balol Ext. I ML .

2. District Mehsana

3. State Gujarat

4. Geographical location in toposheet 46A-2, 46 A-6, 46 A-7, 46 A-11

5. Total Area of the Project 448.89 sq.km

6. Total Cost of the Project 460 Crores

7. Nearest railway station along with distance in kms

Mehsana, 04 km

8. Nearest airport along with distance in kms

Ahmedabad, 60 km

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9. Protected areas as per Wildlife Protection Act,1972 (Tiger reserve, Elephant reserve, Biospheres, National parks, Wildlife sanctuaries, community reserves and conservation reserves)

Not found in the study area

10. Reserved / Protected Forests Not found in the study area

11. Seismicity Zone-III

Table-2 Block details of the study area SL. No.

Name of Block No. of Proposed Wells in each block

Block Area (sq. km)

1 Jotana ML 3 39.50

2 Linch ML 4 43.73

3 Linch Ext – I ML 7 34.25

4 Nandasan Langnaj ML 3 61.90

5 North Shobhasan Ext – I ML 1 56.85

6 Jotana – Warason ML 4 38.05

7 Kadi ML 14 64.49

8 Linch Ext – II ML 2 13.35

9 Mansa ML 2 58.72

10 Jakasana ML 1 9.8

11 East Shobhasan ML 2 22.42

12 Balol Ext. I ML 2 5.83

Total 46 448.89

The details of environmental setting for 10 km radius of the project block area are given below.

The project block is connected through State Highways SH41/SH 19and Mehsana railway

station within ML area;

1.2 Importance of the Proposed Project

India is not among the major producers of crude oil, as it does not have much oil reserves.

Therefore, India depends on imports of crude oil from other countries. There is a heavy imbalance

between oil production and consumption in India. The Indian government is encouraging

exploration and production of oil and gas to a great extent. This would primarily allow India to tap

its own resources there by reducing its import bill. Discovery of viable hydrocarbon reserves in

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the state can boost the state’s economic development to a great extent. The proposed project is

therefore immensely significant for the state and nation.

1.3 Details of Proposed Project

The onshore exploration of oil & gas in the delineated area selected through seismic survey to identify

and establish hydrocarbon potential. The site will be sized to contain all equipment and temporary camps,

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. Within the above constraints, the site shall be sized to minimize environmental impact. The

approximate area of well site is dependent on the type of drilling equipment deployed, which in turn is

dictated by the planned depth of drilling.

1.4 Manpower Arrangement

During the drilling operations, about 10 to 12 persons may be working in 8/12 hour shifts at site. Workers

will be able to return to their camp/homes during duty – off period. Once drilling is over no person is

required at site, except security cover through a contractor.

1.5 Land Requirement

ONGC shall acquire the land apprx. 110m x 110m per well on temporarily basis for the purpose of

preparation of the drill site and drilling operations. The site may require temporary approach road from

an existing one for transportation of rig and other equipment necessary for drilling work. The site shall be

fenced in the event the well is successful. The well site shall be reduced to approximately 30m x 30m for

the production phase and all non-essential areas shall be fully reclaimed as per ONGC’s restoration policy

and land handed over to the land owner.

1.6 Power Requirement

During drilling operations, diesel engines shall be utilized as prime movers for meeting the power required

to run the drilling rig, circulation system etc. A power generator shall also be installed for lighting. The

capacity of the diesel engines that shall be used for operating the rig and the circulation system is

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expected to be of 1250HP (3 Nos, two running and one standby), which will be run by High Speed Diesel.

This generator shall consume approximately 2.5 to 3 KLD of fuel per day, when in operation.

1.7 Water Requirement

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

requirement would be for engine cooling, floor / equipment / string washing, sanitation, fire-fighting

storage / make-up and drinking. During the drilling activity, about 25 m3 per day water will be required

which will include requirements for operation and that for sanitation and drinking of the workers during

drilling single well. The water shall be made available from the nearest ONGC installation, and will be

transported by water tanker. A water pit of approx.100 m3 capacity will be constructed at the site for the

purpose of fire fighting.

2.0 Baseline Environmental Status

Environmental monitoring has been carried within the entire 12 blocks for onshore Exploration of oil &

gas in Mehsana district, Gujarat. The baseline carried out during summer season (27th April to 27th July

2018).

2.1 Land Use Studies

The land use pattern of the proposed project has been studied by District Census Hand Books and satellite

images. The land use pattern of the study area indicates the 84.98 % of land comprises of Agriculture,

Crop Land ( 284089 hectare ), 3.51 % is Agriculture, fallow ( 11726 hectare ), 3.29 % is scrub land (10928

hectare), followed by water bodies (8419 hectare), built up land (8970 hectare) and water bodies (5701

hectare)

2.2 Soil Quality

The soil samples were tested at 8 locations covering various land uses. It has been observed that the pH

of the soil is ranging from 6.49 to 7.48 indicating that the soil is slightly acidic to slightly alkaline in nature.

Moisture found in the range from 0.98 to 1.47%. Conductivity of the soil ranges from 0.078 to 0.672

mS/cm. Texture of the soil in the selected locations of study area were observed to be silty, sandy and

clay loamy in nature. The potassium content varies from 1618 to 3649 kg/ha. Exchangeable Sodium

content varies from 4.15 to10.3 m.eq/100g. Exchangeable calcium and Exchangeable magnesium were

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found in the range between 4.51 to 154 m.eq/100g & 7.3 to 14.3 m.eq/100g respectively. The available

Phosphorous as P ranges from 13.7 kg/ha to 54.7 kg/ha. The available Nitrogen content varies from 207

kg/ha to 346 kg/ha. The Total Nitrogen in the soil is from 271 kg/ha to 505 kg/ha.

2.3 Meteorology

On-site monitoring was undertaken for various meteorological variables in order to generate the site-

specific data. The data generated is then compared with the meteorological data generated by nearest

India Meteorological Department (IMD) stations, located at Ahmedabad.

Meteorological data shows that mean average wind speed during study period are 1.675 m/s while wind

blows from SW direction and Average maximum temperature 39.05°C and minimum temperature 27.5°C

The mean average of maximum relative humidity recorded was 75.5% while mean minimum of 43%.

2.4 Ambient Air Quality

To establish the baseline status of the ambient air quality in the study area, the air quality was monitored

at 11 locations. Out of the 11 locations the minimum and maximum concentration for PM10 ranges between

41.2 and 80.4 g/m3 which are well within the NAAQ standards i.e. 100 g/m3. The minimum and maximum

concentration PM2.5 varies between 18.6 to 45.1 g/m3 respectively during the study period which are well

within the NAAQ standards i.e. 60 g/m3. The concentrations of SO2 ranges between 5.1 to 14.1 g/m 3

which are well within the NAAQ standards i.e. 80 g/m3.The concentrations of NOx were varied between

5.7 to 24.6 g/m3 respectively which are well within the NAAQ standard i.e. 80 g/m3. CO were observed

to be in the range of 0.10 mg/m3 to 0.39 mg/m3. Methane hydrocarbon (CH4 HC) was observed to be below

the detection limit of 0.1 g/m3. Non-methane hydrocarbon (Non-CH4 HC) was observed to be below the

detection limit of 0.1 g/m3. From the analysis of the monitored data, it infers that the air quality levels in

the study area are of fairly good quality and comply with the National Ambient Air Quality Standards

(NAAQ).

2.5 Ambient Noise Level

The noise monitoring has been conducted at 95 locations, covering residential, commercial and silence

zones in the study area. During Day Time the maximum noise level was observed as 55.7 dB (A) dB at

Palavasana part and a minimum of 48.7dB (A) was observed at near Indrap. While During Night time a

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maximum of 42 dB (A) was observed near Indrap, Linch and Lanva and a minimum of 38.4 dB (A) was

observed at Jakasana. A review of this data indicates that at all the locations, the noise level was found

within the permissible limits according to the rule S.O.50 (E), [11/01/2010] - The Noise Pollution

(Regulation and Control) (Amendment) Rules, 2010 except Palavasana part which is a satellite township

of Mehsana town and hence this is due to heavy vehicular traffic in the region.

2.6 Water Quality

The baseline water quality status in the region is established by analysing about 07 ground water samples

and 14 surface water samples during study period.

Ground Water

The pH value of the collected ground water in the study area found to be in the range from 7.57 to 8.01

and conductivity observed in the range 863 µS/cm to 2680 µS/cm. TDS values were observed to be in

range from 480 mg/L to 1512 mg/ L. Total alkalinity is found to be the range from 250 mg/L to 330 mg/L

and Total Hardness ranges from 228 to 560 mg/L. The chloride values of the samples were observed

from 105 mg/L to 645 mg/L and Sulphate values were observed from 8 mg/L to 128 mg/L. The Calcium

and magnesium values were ranged from 43 mg/L to 104 mg/L and 27 mg/L to 73 mg/L respectively. Iron

content observed in the range from BDL (<0.05) mg/l to 0.3 mg/l. Most of the metals are observed as

below the detection limit. Total Coliforms were observed between less than 2MPN/100ml and 26

MPN/100ml and Feacal Coliforms were observed to be less than 2 MPN/100ml.

Surface Water

The pH value of the collected surface water in the study area found to be in the range from 6.61 to 7.52


range from 184 mg/L to 1288 mg/ L. Total alkalinity is found to be the range from 121mg/L to 391mg/L



and magnesium values were ranged from 16 mg/L to 108 mg/L and 12.5 mg/L to 46 mg/L respectively.

Iron content observed in the range from 0.26 mg/L to 5.46 mg/L. COD values observed between 12 mg/L

to 60 mg/L. Most of the metals are observed to be within the detection limit. Total Coliforms were

observed Between 17 MPN/100ml and 900 MPN/100ml and Fecal Coliforms were observed between 4

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MPN/100ml to 80 MPN/100ml.Based on the analyzed parameters, it can be concluded that above surface

water is not fit for drinking purposes unless it is treated and disinfected.

2.7 Biological Environment

As per primary survey and secondary data referred, it can be concluded that the study area is ecologically

rich and diverse.The geography of Mehsana district boasts of having a wide variety of flora and fauna

which are spread throughout its length and breadth. Some of the important mammals found in the study

area are nilgai, chitals, wild boar, four horned antelope and camels etc. A large number of other animals

like snakes, lizards, scorpions, bees, etc., are found in the study area. Many kinds of birds are found

here, such as:, Peacock, Parrots, pheasants, geese ducks and cranes, etc.

Flora in Mehsana district include a wide variety of vegetation. A wide range of climatic condition facilitates

the prevalence of many types of flora., during survey various species of flora are found in one of the

largest dry deciduous forests in the western region of India, including trees like:teak, Boswellia serrata,

Anogeissus latifolia and Diospyros, etc.Owing to the arid climate, the flora and fauna of Gujarat also

possess a wide range of xerophytic vegetation. This kind of vegetation include Acacia Arabica, Acacia

leucophloea, Capparis ophylla and Zizyphus mauratiana, etc. Therefore, as it is evident, Mehsana has

an enormous store of flora and fauna. During survey of the study area, there is no endangered and

endemic fauna or flora found near the study area.

2.8 Socio-Economic Environment

Socio-economic survey has been carried out due to personnel Questionnaire in the study area. As per

the Census of India 2011, the district has population of 13, 43,734 of which 6, 94,397 males and 6, 49,337

females. The overall sex ratio is 935 females per 1000 males. The child sex ratio (0-6 Age) is 890 girls

per 1000 boys. The district has an average literacy rate of 72.30 % with male literacy of 82.90 % and

female literacy of 61.05 %. The population density of the district is 232/sq. km.

In the study area, 68.4 per cent of the population is literate. The gender wise distribution of literates is

male 58.4 per cent and female 41.6 per cent. The overall literacy rate in the study area has been worked

out to 77.7 per cent. The male literacy rate is 89.1 per cent and female literacy rate is 65.9 per cent,

creating a gender gap in literacy rate of 23.2 per cent.

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3.0 Impact Assessment

The identification and assessment of impacts over the various environmental attributes in the region due

to the proposed project activities in the proposed blocks are discussed and mitigated measures and

environmental management plan for the potential impacts have also been presented. Onshore

exploration of oil & gas is a temporary activity which lasts for about 3-4 months at each well location.

3.1 Impact on Topography and Land Use

Onshore exploration of oil & gas project is a short duration activity at each well location, typically

encompassing a period of 3-4 months from land acquisition to site abandonment. The impact would

therefore be localized, temporary and minimal. Because of the above activities, the topographical

structure may change locally. However, considering the small foot print area required during the drilling,

only marginal impact due to change in land use is anticipated.

3.2 Impact on Climate

Impact on the climatic conditions due to drilling will not be significant. The maximum temperatures of the

exit gas from the DG stack and flare stack will be around 300°C and 400°C respectively. In terms of total

emission of greenhouse gases and consequent impact on global warming or on potential for local

increase of ambient temperature, considering the quantum of exit gas and the total duration of flow, the

impact on the local or global climate will be insignificant.

3.3 Impact on Air Quality

The potential sources of air emissions at the well sites will be as follows:

Dust from earth works (during approach road and site preparation);

Emissions from DG sets (including noise emission);

Emissions from possible flaring during well testing; and

Emissions from vehicles

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During the short period of site preparation mechanical shovels and earthmovers will be used for

vegetation clearance, cut and fill and other site leveling activities. These activities could generate dust

particles which can be controlled by sprinkling of water. However, these activities will be only temporary

and the impact to ambient air quality would be within the close proximity of well site.

The gaseous emissions from the DG set will be controlled by efficient combustion of fuel in the DG set.

The flaring of oil and gas during well testing is a short duration activity (about 14 - 21 days) and will be

done within a ground level enclosed pit. Wherever, required special precautions will be taken to minimize

the impact on the local environment and habitat.

3.4 Impact on Surface Water and Groundwater Quality

Drilling operations require the use of water for domestic requirements as well as for operations, but the

use will be of temporary nature and limited to a few days for each well. Hence these impacts are not

significant. The wastewater discharged from the ONGC’s drilling operations shall be collected in HDPE

lined collection pits and solar dried, so no significant impact is envisaged.The clarified wastewater will be

treated in mobile ETP located at the well sites and reutilized. The sewage will be discharged into septic

tanks and then to subsoil through soak pits.

3.5 Impact on Noise Levels

During the proposed project operation at the well sites, there would be various sources of noise in the

area, viz., drilling draw works/rotors, mud pumps, power generators, Vehicular Movement and Cranes

and material handling equipment. Acoustic enclosures would be provided to minimize the Noise impact

of DG sets. The maximum predicted noise level at about 100 m from the boundary of the well site is about

52.0 dB (A). The ambient noise levels at most of the places in the region are within the CPCB standards.

Since, the drilling operations last for only 3-4 months at each location, impact of the noise pollution due

to the proposed exploratory drilling of wells project will be insignificant on the community.

3.6 Biological Impacts

Impact on the ecology of the study area will vary with the proximity of the habitats from the each well

locations. However, the impacts are of temporary nature, which will last only for few months at each well

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location during the proposed project activities and will thus allow subsequent recovery after the activities

stops.

3.7 Demography and Socio-Economics

Although the level of existing communications and support services in the area are considered adequate

based on the population density, establishment of the proposed project would further strengthen the road

network and access to some of the remote areas with all-weather roads would be a distinct beneficial

impact. The overall impact is considered to be positive.

Impact on health due to emissions and noise from proposed project activity has been assessed to be

minimal. In addition employees working at the well site would be provided protective devices like ear

plugs/ear muffs for ensuring minimum impact on human health.

The proposed project should be possible to avoid impact on existing arable land. By following the

compensation procedures and by observing common courtesy, impacts on existing use and benefit rights

holders can be minimized.

The proposed programme is expected to generate local employment in the order of about 10-12 persons

per shift 8/12 hrs. While this benefit is small by most standards, it is a significant employment opportunity

in the block.

4.0 Environment Management Plan

The Environment Management Plan provides a delivery mechanism to address potential adverse

impacts, to instruct contractors and to introduce standards of good practices to be adopted during drilling

operations. For each stage of the programme, the EMP shall list all the requirements to ensure effective

mitigation of every potential biophysical and socio-economic impact. For each impact, or operation, which

could otherwise give rise to impact, the following information is presented:

• A comprehensive listing of the mitigation measures (actions) that ONGC shall implement

• The parameters that will be monitored to ensure effective implementation of the action

• The timing for implementation of the action to ensure that the objectives of mitigation are fully met.

xxv

4.1 Adherence/ Compliance of Eco-Standards

ONGC adheres to various Environment Management System as per international standards. All drilling

& work over rigs are certified ISO 9001, QHSAS 18001 & ISO 14001 for Quality, Health, safety and

Environment Management system. Monitoring and management of environmental aspects being done

for a) Noise monitoring b) Condition monitoring of equipment c) Stack monitoring d) Ambient Air quality

monitoring.

4.2 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, which shall be disposed through septic tanks/soak pits. It is expected that

wastewater in the form of washings shall be generated at an average rate of around 4 m3/day during the

drilling operations from a single well. Waste water will be discharged in HDPE lined pit, and solar dried.

4.3 Atmospheric Emissions

The combustion of diesel for power generation for the proposed project operation results in atmospheric

emissions of SO2, NOx, CO, Particulates and Hydrocarbons. Flaring during production and testing is of

14-21 days duration and atmospheric emissions are marginal.

There will be no sensitive receptors to the emissions of combustion products in the vicinity of the proposed

project operations apart from the crew of the drilling rig. The impacts caused are therefore, considered to

be negligible. Measures to ensure minimal impacts include appropriate management of power generation

source to achieve fuel efficiency and therefore reduce emissions and use of low sulphur diesel oil if

available. Environmental monitoring is proposed during drilling and well testing to ensure maximum

combustion efficiency. Flaring towards any standing vegetation will be avoided. In case if it is inevitable,

a suitable barrier will be erected to prevent any vegetation scorching due to direct heat radiation; and

prior to flaring, the critical equipment will be thoroughly tested.

xxvi

4.4 Noise Environment

The modeling results show that the noise levels will attenuate to below permissible levels within the drill

site boundary. The Generators will be properly enclosed and the exhausts will be provided with silencers.

4.5 Solid and Hazardous Waste Management

The top layer of soil shall be stacked at site for reuse after completion of drilling operations. The solid

waste generated from drilling operation will be disposed in following manner.

Drill Cuttings – 150-600 MT / well will be generated, which are mainly inert solids. Drill cuttings shall be

water washed and then solar dried at site in HDPE lined pit at site. Drill cuttings are collected dried and

disposed off as per GSR 546(E) dated 30th August 2005 guidelines for disposal of solid waste, drill

cuttings and drilling fluids for Onshore drilling process. Dry cuttings shall be covered with top layer of soil.

Spent Oil – During the drilling approx. 200 lts. of spent oil shall be generated. This oil shall be sent to

authorized recyclers, as per ONGC policy.

Oil Sludge/ Hazardous waste – The proposed drilling is temporary activity and exploratory in nature, no

hazardous waste shall be generated. In case of any Oil Sludge/ Hazardous waste is generated during

the drilling activities, same shall be sent for incineration to a TSDF site.

Drilling Mud – Water base drilling mud shall be used, approx. 200m3 -600 m3 drilling mud per well is

required.

4.6 Removal of Equipment and Materials

In the event if economic quantities of hydrocarbons are found, the well will be suspended with a wellhead

in place for producing oil and gas, but all other equipment and materials will be removed from the site.All

empty drums, wastes, used and unused drilling fluids, fuel and lubricants will be removed from the well

site. Water supply and effluent discharge hoses and associated equipment will be removed. The access

road(s) would be reinstated.

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4.7 Decommissioning upon Abandonment

In the event that no economic quantities of hydrocarbons are found, a full abandonment plan will be

implemented for the well sites in accordance with the applicable regulations (OMR).

5.0 Environmental Mitigation

The exploratory drilling program shall be designed to avoid or minimize impacts to the environment and

local communities wherever practicable & desirable. ONGC is committed towards environment protection

with a target to achieve exploration and production goals. One of the very important part of environment

protection is the selection of location of proposed exploratory wells so that it should not affect the land

use pattern of the area, which is very important component of environment. In general locations of the

wells are decided at a safe distance from the dwellings, avoid minimum interferences with agricultural

activities, community infrastructure and also to avoid disturbances to forest lands and otherwise sensitive

or unique habitats. Wherever residual impacts remain, environment, mitigation measures shall be taken

to reduce the impact to an acceptable level or adequately offset it.

6.0 Environmental Monitoring

The following will be monitored on a regular basis throughout the life of the project to ensure a high level

of environmental performance being maintained:

• Oil content in produced water;

• Materials used in drilling fluid make up;

• Fluid losses;

• Baseline sampling prior to any drilling activity to establish pre-project environmental characteristics.

7.0 Occupational Health Surveillance Programme

This includes identification and control of health hazard and health care. Deployed Rig crew shall go for

periodic health check-up as company policy.

xxviii

8.0 Risk and Disaster Management Plan

In view of the hazardous nature of products / process handled by the ONGC, site specific Disaster

Management Plans (DMPs) are in place. These plans are based on various probable scenarios like Well

Blow Out, Fire, Explosion, Natural Calamities etc. The consequence arising out of such incidents are

accurately predicted with the help of latest technique available by various Risk Analysis Studies. To

minimize the extent of damage consequent to any disaster and restoration of normalcy is the main

purpose of DMP. There are on site Emergency Plans that deal with handling of the emergency within

boundary of the plants mainly with the help of industry’s own resources. Also when the damage extends

to the neighbouring areas, affecting local population beyond boundaries of plant, Off-site Emergency

plans is put into action in which quick response and services of many agencies are involved e.g.

Government, Fire Services, Civil defence, Medical, Police, Army, Voluntary organizations etc. EMPs are

reviewed periodically.

8.1 Objective of DMP

The following are the main objective of Disaster Management Plan:

Safeguarding lives both at installations and in neighbourhood.

Containing the incident & bringing it under control.

Minimizing damage to property & environment.

Resuscitation & treatment of causalities.

Evacuating people to safe area.

Identifying persons and to extend necessary welfare assistance to causalities.

Finally when situation is controlled, efforts are to be made to return to normal or near normal

conditions.

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9.0 Project Benefits

The proposed program will establish hydrocarbons in the block. The exploration of the oil field will result

in considerable growth of service sector and will also generate new industrial and business opportunities

in the area. The major benefits of the project include reduction of the oil import bill of the nation as well

as reduction of the imbalance in oil production and consumption. Further commercial development will

also lead to investment in Gujarat, bringing oil and gas revenues both to the State and to the Central

Government. The presence of ONGC in the region will further substantially improves the socio-economic

conditions of the region. In operation phase ONGC requires significant work force of non-technical and

technical persons. Migration of persons with better education and professional experience will result in

increase of population and literacy in the surrounding villages.

10.0 Conclusions

The proposed project has certain level of marginal impacts on the local environment. However, the

proposed project has significant beneficial impact/effects in terms of providing the employment

opportunities and various CSR practices to be followed by ONGC. Growth and development, in harmony

with the environment, has always been the approach of ONGC.

The conclusions of EIA are:

The proposed project meets the compliance requirements of various environmental

regulations;

Adoption of environmental friendly Best Management Practices results in minimising the

impacts on environment;

Community impacts of the project will be beneficial, as the project will generate significant

economic benefits for the region;

The post drilling, commercial developmental activities of ONGC can reduce the import

burdens of crude oil to the nation; and

xxx

With the effective implementation of the Environment Management Plan (EMP) during

the planning, design, construction and operation phases, the exploratory project can proceed

without significant negative impact on the environment.



Rev. No. 02


Chapter No. 01

1

CHAPTER-1

INTRODUCTION



Rev. No. 02


Chapter No. 01

2

1.0 Introduction

Oil and Natural Gas Corporation Limited (ONGC) is a Public Sector Undertaking (PSU) of the

Government of India, under the administrative control of the Ministry of Petroleum and Natural Gas

(MoPNG). It is India's largest oil and gas exploration and production company. It produces around 70%

of India's crude oil (equivalent to around 25% of the country's total demand) and around 60% of its natural

gas. This largest natural Oil & gas company ranks 11th among global energy majors (Platts). It is the only

public sector Indian company to feature in Fortune’s ‘Most Admired Energy Companies’ list. ONGC ranks

18th in ‘Oil and Gas operations’ and 183rd overall in Forbes Global 2000. Acclaimed for its Corporate

Governance practices, Transparency International has ranked ONGC 26th among the biggest publicly

traded global giants. It is involved in production of hydrocarbons in 26 sedimentary basins of India, and

operates over 25,500 kilometres of pipelines in the country, including sub-sea lines.

1.1 Purpose of the Report

As per Environmental Impact Assessment EIA Notification dated 14th September, 2006, onshore

exploration, development and production of oil & gas project falls under category ‘A’ of activity 1(b)

requires prior Environmental Clearance (EC) to be obtained from MoEF&CC before the commencement

of ground activity.

The application for prior EC (Form-1 and Pre-feasibility Report) for Exploration of oil and gas in 46 wells

(Onshore) of 12 ML Blocks of Western Onshore Basin has been submitted to MoEF&CC on 25th April

2018 and Terms of Reference (TOR) has been issued by MoEF&CC vide letter reference F. No. IA-J-

11011/158/2018-IA-II (I) and Proposal No. IA/GJ/IND2/74678/2018 dated 1st June 2018. A copy of the

TOR letter, along with its compliance is enclosed.

This EIA Report is prepared in line with the TOR issued by MoEF&CC and addresses the anticipated

environmental impacts of the proposed project and proposes the mitigation measures for the same for

obtaining Environmental Clearance (EC) from MoEF&CC, New Delhi. The report covers the primary data

collected during 3 months of Summer Season.



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1.2 Identification of Project and Project Proponent

1.2.1 Identification of Project

Forty Six (46) exploratory wells of 12 ML Blocks of Western Onshore Basin are proposed to be drilled to

evaluate the hydrocarbon potential lies in the Mehsana District of Gujarat state.

1.2.2 Project Proponent

Western Onshore Basin, Vadodara; is engaged in exploration activities in the Mehsana District of Gujarat

state, in Cambay Basin. The Cambay basin is a proven and rich petroleum province and has generally

favourable combination of source sediments, reservoir rocks, regional seals and traps. The Cambay

basin is the main source rock sequence in the basin along with minor contributions of oil from Kalol,

Tarapur and Olpad formation. The fluvio-deltaic sediments of the Kalol and Ankleshwar formations of

upper Eocene age are the main reservoirs. Oil trapped in these upper Eocene reservoirs are effectively

sealed by the Tarapur/Kanwa shales of upper Eocene-Oligocene age. A favourable combination of

reservoir-source-cap in the Eocene –Oligocene sequence of the basin formed essentially one petroleum

system. This can be divided into two sub systems depending on its development in the Northern and

Southern part of the basin. The Cambay shale-Kadi/Kalol Tarapur petroleum system in the northern part

of the basin (Cambay-Tarapur and Ahmedabad-Mehsana Blocks, and the Cambay shale – Hazad-Kanwa

petroleum system in the southern part of the basin (Narmada and Broach Jambusar blocks). The said

ML Blocks are with ONGC since 1965 with 100% operatorship and producing blocks. In support of the

long term hydrocarbon exploration program, ONGC proposes to drill exploratory wells in the said ML

Blocks in deeper prospects.

1.2.3 Proposed Project

As per the proposed project, Forty Six (46) of exploratory wells to be drilled in12 ML Blocks of Mehsana

District of Gujarat state, in Cambay Basin in the Oil and Natural Gas Corporation Ltd (ONGC) operated

acreages. 46 locations (Onshore) of 12 ML Blocks were considered after 2D and 3D seismic data

acquisition processing and interpretation. The targeted depths of proposed exploratory wells shall be up

to 2000-3000 mts. The said ML Blocks are with ONGC with 100% operatorship and are producing Blocks



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till date. In support of the long term hydrocarbon exploration program, ONGC proposes to drill exploratory

wells in the 12 ML Blocks in new prospects.

1.3 Brief Description of the Project

1.3.1 Nature of the Project

The proposed project intends to identify the onshore exploration of oil & gas in Forty Six (46) wells in the

Mehsana District of Gujarat state, in Cambay Basin in the Oil and Natural Gas Corporation Ltd (ONGC)

operated acreages.

1.3.2 Size of the Project

ONGC has identified onshore 46 exploratory wells of oil & gas in non–forest area of 12 ML blocks in

Mehsana district of Gujarat. The proposed project falls in a fairly well explored, productive hydrocarbon

basin of Cambay Basin. Operational areas for the 12 Blocks covered in this study having an area of

448.89 Sq Km.

1.3.3 Project Site Details

Brief description of the project is given in Table 1.1. Details of block coordinates is given in Table 1.2.The

study area map showing the block location are shown in Figure-1.1 and the topographical sheet of the

block location are given in Figure 1.2



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Figure 1.1: Index Map of the Area



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Figure 1.2 Topographic Sheets of Block Locations in Mehsana District



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Table 1.1: Brief Description of the Project

S. No. Item Details

1. Name of the Project Exploratory drilling of Forty Six (46) wells in 12 ML Blocks

of Western Onshore Basin lies in the Mehsana District of

Gujarat state.

2. Project Sector 12 ML Blocks of Western Onshore Basin

3. Location of the Project Mehsana District of Gujarat state

4. Project Region Cambay Basin of Mehsana District

5. Block Area (Sq. Km.)

Jotana ML-39.50 sq. km ;

Linch ML 43.73 sq. km ;

Linch Ext – I ML 34.25 sq. km ;

Nandasan Langnaj ML 61.90 sq. km ;

North Shobhasan Ext – I ML 56.85 sq. km ;

Jotana – Warason ML 38.05 sq. km ;

Kadi ML 64.49 sq. km ;

Linch Ext – II ML 13.35 sq. km ;

Mansa ML 58.72 sq. km ;

Jakasana ML 9.8 sq. km ;

East Shobhasan ML 22.42 sq. km ;

Balol Ext. I ML 5.83 sq. km.

6. Total Block Area of the

Project 448.89 sq. km

7. Total Cost of the Project

460 crores



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Table 1.2 Details of Block Coordinates

S.No. Block Name

Area (Sq.Km.)

Point Latitude Longitude

Deg. Min. Sec. Deg. Min. Sec.

1

Jotana -ML

( 39.50)

a 23 28 46.744 72 17 12.94

b 23 28 9.743 72 16 47.95

c 23 27 28.746 72 17 10.36

d 23 28 7.738 72 18 4.928

e 23 25 6.65 72 20 28.421

f 23 32 52.724 72 18 34.949

a 23 28 46.744 72 17 12.941

2 Linch ML

( 43.73 )

h 23 24 51.75 72 20 39.926

i 23 23 31.751 72 22 27.908

j 23 26 1.738 72 25 9.89

k 23 29 25.728 72 28 5.876

l 23 30 0 72 27 19.876

m 23 29 13.733 72 26 15.007

n 23 29 13.733 72 26 15.886

o 23 27 37.732 72 26 15.886

p 23 27 37.735 72 24 31.91

q 23 28 2.838 72 24 31.91

g 23 27 43.736 72 24 3.899

h 23 24 51.75 72 20 39.926

3 Linch Extn-I ML

( 34.25 )

r 23 24 58.748 72 18 33.736

s 23 22 37.758 72 19 13.937

t 23 22 35.562 72 19 7.54

u 23 21 42.761 72 19 38.928

v 23 20 58.765 72 19 56.917

w 23 22 1.758 72 22 18.901

x 23 23 31.751 72 22 27.908



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y 23 24 51.751 72 20 39.926

z 23 25 52.748 72 19 52.417

r 23 24 58.748 72 18 33.736

4 Nandasan -Langnaj ML

( 61.90)

A 23 29 25.728 72 28 5.876

B 23 26 1.738 72 25 9.89

C 23 24 26.748 72 23 26.902

D 23 22 57.749 72 25 6.892

E 23 23 52.746 72 27 10.89

F 23 25 16.741 72 29 42.871

G 23 26 1.734 72 29 5.878

H 23 26 13.736 72 29 57.869

A 23 29 25.728 72 28 5.876

5

North Sobhasan Extn-I ML

( 56.852 )

I 23 38 43.303 72 24 49.496

J 23 43 39.583 72 20 14.431

K 23 42 53.683 72 18 57.946

L 23 35 19.712 72 21 47.138

M 23 37 11.705 72 21 49.914

N 23 37 11.705 72 22 41.93

O 23 37 11.705 72 23 7.908

I 23 38 43.303 72 24 49.496

6 Jotana -Warosan ML

( 38.05 )

P 23 30 10.735 72 19 14.329

Q 23 28 8.339 72 19 44.342

R 23 26 37.741 72 22 46.312

S 23 27 43.736 72 24 3.899

T 23 30 1.732 72 23 20.918

U 23 30 1.732 72 22 24.924

V 23 30 33.131 72 22 15.01

W 23 30 24.329 72 21 45.925

X 23 30 1.732 72 21 51.912

Y 23 30 17.73 72 19 57.94

P 23 30 10.735 72 19 14.329

7 Kadi-ML

(64.49)

P 23 25 26.749 72 17 25.955

Q 23 24 44.057 72 16 12.353

R 23 15 39.78 72 18 51.934



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S 23 16 40.778 72 20 11.908

T 23 19 7.778 72 20 43.904

U 23 20 58.765 72 19 56.917

V 23 21 42.761 72 19 38.929

P 23 25 26.749 72 17 25.955

8 Linch Extn-II ML

( 13.35 )

P 23 28 8.339 72 19 44.342

Q 23 25 6.65 72 20 28.421

R 23 24 51.75 72 20 39.926

S 23 26 37.741 72 22 46.312

P 23 28 8.339 72 19 44.342

9 Mansa

(58.72)

A 23 35 51.698 72 34 57.853

B 23 35 48.707 72 34 3.864

C 23 33 26.708 72 33 48.838

D 23 30 6.718 72 35 0.841

E 23 30 6.721 72 33 37.85

F 23 26 9.737 72 35 13.83

G 23 26 56.728 72 37 35.814

H 23 25 21.734 72 38 57.818

P 23 25 54.732 72 40 13.807

Q 23 27 31.723 72 39 14.818

R 23 27 53.719 72 40 29.795

S 23 28 15.726 72 40 15.816

T 23 28 1.726 72 37 55.808

U 23 28 34.223 72 37 52.813

V 23 28 31.724 72 36 52.837

W 23 30 6.718 72 35 52.829

X 23 34 8.706 72 34 22.836

A 23 35 51.698 72 34 57.853

10 Jakasana

(9.8)

A 23 26 54.442 72 17 29.335

B 23 27 1.746 72 17 57.952

C 23 24 58.748 72 18 33.736

D 23 25 52.748 72 19 52.417

E 23 26 50.741 72 19 6.445

F 23 26 31.747 72 18 44.939



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G 23 26 49.744 72 18 22.943

H 23 27 16.646 72 18 44.831

I 23 28 7.738 72 18 4.928

J 23 27 28.746 72 17 10.36

A 23 26 54.442 72 17 29.335

11 East Shobhasan

(22.422)

P 23 35 40.211 72 27 37.897

Q 23 35 3.71 72 27 35.892

R 23 33 51.71 72 27 33.887

S 23 33 54.713 72 25 37.909

T 23 32 22.722 72 25 47.107

U 23 32 22.718 72 29 34.886

V 23 33 31.709 72 29 36.863

P 23 35 40.211 72 27 37.897

12 Balol Extn-I

(5.83)

a 23 38 7.71 72 12 45.983

b 23 37 9.714 72 12 37.987

c 23 37 9.714 72 14 5.982

d 23 37 11.69 72 14 18.366

e 23 37 40.714 72 14 9.964

f 23 38 49.711 72 14 9.964

a 23 38 7.71 72 12 45.983

1.3.4 Importance of the Project

India is highly dependent on import of crude oil. Net imports of crude oil is 202.85 MTs during 2015-16.

Although more than 70% of its crude oil requirements and part of the petroleum product requirement is

met from imports, India has developed sufficient processing capacity over the years to produce different

petroleum products. As result, India is now a net exporter of petroleum products. The export of petroleum

products increased to 60.53 MT during 2015-16.

Energy security has become one of the top three goals of the Indian Government. The Indian Government

is encouraging development and production of oil and gas to a great extent. This would primarily allow

India to tap its own resources there by reducing its import bill.



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Discovery of viable hydrocarbon reserves in the state can boost the state’s economic development to a

great extent. It would also catalyse influx of industries in the state. The proposed exploration project is

thus of immense significance for the Country. Extraction of hydrocarbons in these blocks will substantially

improve the socio-economic conditions of the region. The proposed project will also help to discover the

geological past to create the economic future for the region as well as to the country.

1.4 Scope of the Study

With a view to assess the environmental impacts arising due to the proposed drilling for oil & gas in 12

blocks in Mehsana district, Gujarat, ONGC being NABET accredited organization had prepared EIA

report for various environmental components including air, noise, water, land and biological components

along with parameters of human interest which may be affected and also prepared an Environmental

Management Plan (EMP) for mitigating adverse impacts.

ONGC has availed the services of M/s. ABC Techno Labs India Private Limited, Chennai to undertake

Baseline Environment Monitoring. ABC Techno Labs India Private Limited is an ISO 9001:2008,

ISO14001: 2004, OHSAS 18001:2007 certified company and accredited by National Accreditation Board

for Testing and Calibration Laboratories (NABL).

Environmental baseline monitoring has been carried out during three months representing summer

season and used to identify potential significant impacts. The scope of the present study is in-line with

the TOR as recommended by MoEF&CC. The scope of study broadly includes:

To conduct literature review and to collect data relevant to the study area;

To undertake environmental monitoring so as to establish the baseline environmental status

of the study area;

To identify various existing pollution activities in the ambient levels;

Establishing the relevant features of the proposed project that are likely to have an impact

on the environment;

Predicting the impacts on the environment due to proposed project;

To evaluate the predicted impacts on the various environmental attributes in the study area

by using scientifically developed and widely accepted environmental impact assessment

methodologies;

To prepare a Disaster Management Plan (DMP) based on Risk Assessment, studies;



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To prepare an Environment Management Plan (EMP) outlining the measures for improving

the environmental quality and scope for future proposed project activities and Occupational

Health and Safety for environmentally sustainable development; and

To identify critical environmental attributes required to be monitored.

The literature review includes identification of relevant articles from various publications, collection of data

from various Government agencies and other sources.

1.4.1 Administrative and Legislative Background

The principal Environmental Regulatory Agency in India is the Ministry of Environment and Forest and

Climate Change (MoEF&CC), New Delhi. MoEF &CC formulates environmental policies and accords

environmental clearance for the projects.

1.4.2 Study Area for EIA The study area for the EIA covers the 10 km radius from the boundaries of 12 blocks in Mehsana district. The total block area is considered as the study area.

1.4.3 Methodology of the Study

Engineers and scientist of M/s. ABC Techno Labs India Private Limited, Chennai along with ONGC officials had conducted a reconnaissance survey and sampling locations were identified on the basis of:

Collection, collation and analysis of baseline data for various environmental attributes viz Ambient air quality, Water quality, Soil, and Noise etc.

Predominant wind directions in the study area as recorded by India Meteorological Department (IMD);

Existing topography, location of surface water bodies like ponds, canals and rivers;

Location of villages/towns/sensitive areas;

Accessibility, power availability and security of monitoring equipment, pollution pockets in the area; and

Areas which represent baseline conditions.

Field studies have been conducted for a period of three months (27th April to 27th July, 2018) representing

summer season to determine existing conditions of various environmental attributes as outlined in Table-

1.3.



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TABLE-1.3 ENVIRONMENTAL ATTRIBUTES AND FREQUENCY OF MONITORING

Sr. No

Environmental Component

Sampling Locations

Sampling Parameters

Total Sampling

Period

Sampling Frequency

1 Meteorology One central location

Temperature, Wind Speed, Wind Direction, Relative Humidity, Rainfall

One non monsoon season (Three months)

Continuous hourly recording

2 Ambient Air Quality

11 Locations PM2.5, PM10, SO2, NOx, CO, VOC & BTX, THC CH4-HC and

non CH4-HC

Two consecutive days per week

24 hourly samples

3 Water Quality 14 Locations of surface water & 07 locations of Ground water

As per IS: 10500 Grab sampling Once during study period

4 Noise Monitoring 95 Locations Sound Pressure Levels

Continuously for 24 hours

Once during study period

5 Soil Analysis 08 Locations within study area

Physical and Chemical characteristics

Composite sample

Once during study period

6 Ecology Terrestrial Ecological Locations & Aquatic location within study area

Flora and fauna Field observations and secondary sources

Once in study period

7 Demography and Socio-economic aspects

Total block area Demographic profile

Based on District Census Handbook (2011) and field observations



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Sr. No

Environmental Component

Sampling Locations

Sampling Parameters

Total Sampling

Period

Sampling Frequency

8 Land Use Total block area Trend of land use

change for different

categories

Based on District Census Handbook

(2001) and satellite images

9 Geology - Geological history

Data collected from secondary

sources

10 Hydrology - Drainage area and

pattern, nature of streams, aquifer characteristics, recharge and discharge rates

Based on data collected from

secondary sources

Apart from the primary data on the existing baseline quality status of various environmental components,

a summary of physical, natural, social and cultural environment has also been provided incorporating

secondary data collected from various sources.

1.5 Contents of the Report

The report has been framed in eleven chapters and presented as follows:

Chapter-1.0: Introduction

This chapter provides background information of the project, brief description and objectives of the project,

description of the area, scope, methodology and organization of the study.

Chapter-2.0: Project Description

This chapter presents the information on the proposed project activities, technology being adopted, sources

of pollution and proposed control measures.

Chapter-3.0: Description of the Environment

This chapter presents the methodology and findings of field studies undertaken to establish the baseline

conditions.



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Chapter-4.0: Anticipated Environmental Impacts and Mitigation Measures

This chapter details the inferences drawn from the environment impact assessment of the project during

Exploration, development and production phase. It describes the overall impacts of the project and

underscores the areas of concern which need mitigation measures.

Chapter-5.0: Analysis of Alternatives

This chapter presents the analysis of alternative sites and technologies considered for the proposed

project.

Chapter-6.0: Environmental Monitoring Programme

This chapter provides recommendations for Environment Management Plan (EMP) including mitigation

measures for minimizing the negative environmental impacts of the project. Environmental monitoring

requirements for effective implementation of mitigative measures during operation of the project along

with required institutional arrangements for their implementation.

Chapter-7.0: Additional Studies

This chapter covers the details of risk involved in the project, public hearing, Disaster Management Plan

(DMP), Occupational Health and Safety (OHS) and summary of other special studies as per TOR

conditions.

Chapter-8.0: Project Benefits

This chapter presents the details of proposed Corporate Social Responsibility (CSR) activities and the

benefits of the project to the community.

Chapter-9.0: Environmental Cost Benefit Analysis

This chapter contains the Cost benefit analysis from environment point of view.



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Chapter-10.0: Environment Management Plan

This chapter contains the detailed Environment Management Plan.

1.6 Status & Stage of Regulatory Framework

As per the Schedule attached to the EIA Notification 2006, as amended till date, the proposed project is

covered under Project or Activity, 1(b), namely Offshore and Onshore Oil and Gas Exploration,

Development and Production. Such activities are also listed as Category A under the said Notification,

requiring prior Environment Clearance (EC) from the Impact Assessment Authority (IAA), i.e. the Ministry

of Environment, Forests & Climate Change (MoEF&CC), New Delhi.



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Chapter 2

Project Description



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2.0 PROJECT DESCRIPTION 2.1 Introduction

This chapter presents the project information including technical details of the proposed Exploration of oil

& gas operations, utilities and services, infrastructure facilities and sources of pollution. The expected

quantum of the waste generation and treatment and safe disposal of the waste are also discussed in the

chapter.

2.2 Type of the Project

The hydrocarbon reserve data obtained from the various wells drilled so far have shown very encouraging

results. So far more than 500 numbers of wells (including exploratory wells) have been drilled in this field.

A lot of scope still exists in exploring new sub-surface structures in this area for hydrocarbons. Hence,

ONGC has planned to drill 46 wells in 12 blocks in Mehsana district, Gujarat.

2.3 Need of the Project

The demand for petroleum has recorded a considerable increase over the year from 30 million tonnes in

1980-81 to about 115 million tonnes at present. This growing demand poses a big challenge to oil

producing companies. Proposed drilling activities will be under taken by ONGC in these blocks may lead

to in helping meet some part of the rising oil and gas requirement of the country . By drilling exploratory

well new discovery can be made for future oil demand. Also, new oil finds of the blocks will lead to

reduction in India’s dependence on imported crude oil and thereby resulting into considerable saving in

foreign exchange.

Demand-Supply Gap

Presently India is importing 75% of its required crude oil.

Export Possibility



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Nil, Indian domestic market is deficient in supply and hence all the production will be utilized locally if any

after completion of exploratory drilling phase.

Domestic / Export Markets

All produced crude oil can be refined in India and sold locally. In case of gas, it would be fed through the

pipeline within the state to local consumer.

Employment Generation (Direct and Indirect) due to the Project

Direct

~30-40 local persons will be deployed at the drilling rig for a short duration of about 60-90 days

Indirect

~8-10 persons would be engaged in providing support services to the drilling operation including

warehouse support (managing the logistics of securing and supplying the required materials for the

project).

2.4 Project Location and Project Details

ONGC has identified 46 wells for Exploratory drilling in 12 onshore ML blocks in Mehsana district, Gujarat

covering Linch, Shobhasan, Kadi and Mansa oil fields.

2.4.1 Typical Well Site Details

The 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. Within the above constraints, the

site shall be sized to minimize environmental impact. The approximate area of each well site is dependent

on the type of drilling equipment deployed which in turn is dictated by the planned depth of drilling.



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Minimum land required at each well site during drilling will be 110 m x 110 m, i.e., 1.21 ha. On an average,

the land requirement at each well site, including site facilities and camp site is considered as 1.21-1.5 ha.

Each well site will require the following facilities:

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

Drilling rig foundation and celler;

Foundation / pits for ancillary equipment;

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

Waste storage pits;

Cutting disposal (impervious lined) pits;

Waste storage pit;

Septic tank with soak away pits;

Paved and contained chemical storage area;

Above ground diesel storage tanks with paved and bounded area;

Radio room;

Storm water drainage system;

Internal roads and fencing.

In the proposed project, each well sites will be restricted access area and fenced all round with round the

clock watch and ward facility. Entry of vehicles into the drilling site area will be prohibited except for

material movement. Adequate parking facilities will be provided outside the drilling location.

2.5 Size or Magnitude of Operation

The proposed drilling in 12 onshore ML blocks covering an area of 448.89 km2 to establish the presence

of hydrocarbon reserves. The estimated cost of the proposed project is approximately Rs. 460 Crores. The



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salient features of the project and magnitude of various resources required for the project is given in Table-

2.1.

TABLE-2.1 SALIENT FEATURES OF THE PROPOSED PROJECT

Sr. No. Features Details

1 Total block area in the district 12 Blocks of area 448.89 sq.km in Mehsana district, Gujarat

2 Project Operator Oil and Natural Gas Corporation Limited (ONGC)

3 Proposed number of wells 46 wells

4 Depth of wells 2000-3000 m (approximately)

5 Estimated project cost Total of Rs. 460 Crores

6 Duration of drilling 3 - 4 months for each well

7 Land requirement at each well site including site facilities and camp site

Total Average 1.5-2.25 ha At each well site: about 1.56 ha Base Camp: 0.5 ha

8 Water requirement 25 m3/day

9 Drill cuttings generation at each well site

up to 500 m3/well approximately

10 Drilling Wastewater generation at each well site

About 04 m3/day (for solar evaporation in lined pit at drilling site)

11 Domestic wastewater generation at each well site

01 m3/day ( in septic tank, followed by soak pit)

12 Power requirement for each well

1250 kVA X 2 nos & 1 nos standby

13 Manpower requirement for each well

Approx. 20 per shift of 12 hrs.

2.5.1 Resource Requirement for the Project

2.5.1.1 Land Requirement

The minimum land required at each well site during Exploration of oil & gas will be 110 m x 110 m, i.e., 1.21-1.5 ha. The land will be acquired on a temporary basis and if commercial quantity of oil or gas is found, the land will be taken on long lease and if oil and gas is not found in commercial quantities, the land will be returned to the owner by restoring the land as per restoration policy of ONGC.

2.5.1.2 Water Requirement

Water is basically required for preparing drilling mud, direct washing of drill cuttings, cooling of gas engines and for meeting domestic needs of the campsite. Typically, the water consumption for each well will be 25 m3/day. However, the drilling and domestic water requirement would depend on the time required to drill



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the well, which is primarily dependent on the proposed depth. Table-2.2 gives the water consumption for a typical each well site. Water balance diagram of each well site is given in the Figure: 2.1

TABLE-2.2 WATER REQUIREMENTS FOR EACH WELL SITE

S. No. Purpose Peak water required during Drilling period (KLD) per well

Drilling Operation

1 Mud preparation 18

2 Drill cutting washing 05

Derrick floor Washing

3 Desander 05

Desilter

4 Domestic requirement 05

5 Mud Pump / Equipment Cooling 02

Total Water requirement for Drilling (KLD) 35

Actual Requirement of fresh water (KLD) 25



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Figure 2.1: Water Balance of each well site The water requirement will be met through water tankers from nearby ONGC Installations. Suitable water transport arrangement will be made to transfer water for both drilling and domestic purposes.

2.5.1.3 Power Requirement

The power requirement of the drilling rig will be catered through 03 Nos of 1250 kVA Diesel Generator (DG) sets with 1 Nos of DG set will be kept as Stand by. The DG set details and fuel requirements is given in Table-2.3.



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TABLE-2.3 DETAILS OF DG SETS

Location DG Capacity Operational Stand by Fuel Requirement

Drilling site 1250 kVA 2 1 2.5-3.0 KLD

2.5.1.4 Manpower Requirement

The each well site construction would be done largely by employing local labor. At each well site construction, local employment will be generated for about 10 person/shift.

2.5.1.5 Drilling Mud

Only water-based drilling mud will be used for the drilling of all wells. Drilling of wells requires specially formulated muds which basically comprise inert earth materials like bentonite, barite in water with several additives to give mud weight, fluidity and filter cake characteristics while drilling. The drilling muds have several functions like lubrication and cooling of the drill bit, balancing subsurface formation, bringing out the drill cuttings from the well bore, thixotropic property to hold cuttings during non-operations, formation of thin cake to prevent liquid loss along well bore etc. Several additives are mixed into the mud system to give the required properties. Water based mud will be used to the possible extent in the drilling but use of synthetic based mud may require due to complexities associated with the geological formation and associated hole stability problems.

The constituents of water based mud (WBM) are given in Table-2.4. The special additives and their functions in WBM are shown in Table-2.5.

TABLE-2.4 CONSTITUENTS OF WATER BASED MUD (WBM)

Sr. No Chemicals

1 Barite

2 Bentonite

3 Carboxy Methyl Cellulose

4 Mud Thinner / Conditioner

5 Resinated Lignite

6 Non-Weighted Spotting Fluid

7 Weighted Spotting Fluid

8 EP Lube

9 Drilling Detergent

10 Caustic Soda

11 Potassium Chloride

12 Soda Ash



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TABLE-2.5

SPECIAL ADDITIVES AND THEIR FUNCTIONS IN WATER BASED MUD

Sr. No. Discharge Category Exploration

1 Sodium bicarbonate Eliminate excess calcium ions due to cement contamination

2 Sodium chloride Minimize borehole washout in salt zone

3 Groundnut shells, mica of cellophane Minimise loss of drilling mud to formation

4 Cellulose polymers or starch Counter thick, sticky filter cake, decrease filter loss to formation

5 Aluminium stearate Minimize foaming

6 Vegetable oil lubricant Reduce torque and drag on drill string

7 Pill of oil based mud spotting fluid Counter differential pressure sticking of string. Placed down hole opposite contact zone to free pipe.

The main components of drilling mud are slurry of inert solids suspended in a liquid phase. The main constituents of the water-based mud are Bentonite and Barites and Calcium carbonate, all of which are natural minerals. The role of the mud in pressure control is especially important. The density of the mud can be increased by the addition of barite weighting material. Bentonite and Calcium carbonate are employed to improve the theological properties and enable the drill cuttings to be transported from the hole while drilling and also be suspended in the fluid while the drill bit is being changed. The barite used in the drilling mud would be as per American Petroleum Institute (API) standard specifications.

If Synthetic Based Drilling mud (SBM) need to be used after certain depth, synthetic mud will be recycled completely and at the end of the drilling activities, drilling mud is collected and reused in subsequent drilling operations.

2.6 Proposed Schedule for the Project Approval and Implementation

The duration of various stages of the proposed project is given as under:

The duration of construction works including site excavation, preparation and well pad construction is expected to last approximately thirty days for each well site.

Well testing operation will be done over a period of 2-3 days.

Abandonment and restoration of the each well site is expected to take about one month.

Thus, on an average, site preparation and drilling of one well is likely to take approximately 3-4 months under normal conditions. Working hours during the Exploration activity will be 24 hours per day, seven days per week with 12 hours per shift.



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2.7 Technology and Process Description

The activity involves drilling of the hole across various ground layers to a predetermined depth. Drilling

operations in on land areas are generally the same irrespective of geographical area of operation. Drilling

operation is carried out using an electrically operated rig. A typical drilling rig sketch is shown in Figure-

2.2

Drilling unit for exploration of oil & gas wells consists of a derrick at the top of which is mounted a crown

block and a hoisting block with a hook. From the swivel is suspended a Kelly stem which passes through

a square or hexagonal Kelly bush which fits into the rotary table. The rotary table receives the power to

drive it from an electric motor. The electric motor rotates the rotary table, through which passes the Kelly

bush, and the rotations are transmitted to the bit as the drilling progresses, the drill pipes in singles are

added to continue the drilling process. At the end of the bit life, the drill pipes are pulled out in stands and

stacked on the derrick platform. A stand normally has 3 single drill pipes. After changing the bit, the drill

string is run back into the hole and further drilling is continued. This process continues till the target depth

is reached.

During the course of drilling, cuttings are generated due to crushing action of the bit. These cuttings are

removed by flushing the well with duplex/triplex mud pumps. The mud from the pump discharge through

the rotary hose connected to stationary part of the swivel, the drill string and bit nozzles. The mud coming

out of the bit nozzles pushes the cuttings up the hole and transports them to the surface through the

annular space between the drill string and the hole. The mud not only carries away crushed rock from

the bottom of the hole but it also cools the bit as it gets heated due to friction with formation while rotating.

The hydrostatic head of the mud helps in balancing subsurface formation pressures thereby preventing

uncontrolled flow of formation fluids into the well bore; in extreme cases this phenomenon is termed blow-

out, a rare occurrence.

At the surface, the mud coming out from well along with the cuttings falls in a trough, passes through the

solids control equipments i.e. shale shaker of 1200 GPM capacity, desander of 1200 GPM capacity,

desilter of 1200 GPM capacity and mud cleaner. These equipments remove the solids of different sizes,

which get mixed with the mud during the course of drilling. The cleaned mud flows back to the suction



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tanks to be again pumped into the well. The drilling mud/fluid circulation is thus a continuous cyclic

operation. The most suitable clay for mud preparation is bentonite, which is capable of forming highly

dispersed colloidal suspensions. Various other chemicals are also used in mud preparation as per

requirements dictated by the temperature/pressure conditions of the wells. The mud is continuously

tested for its density, viscosity, yield point, water loss, pH value etc. to ensure that the drilling operations

can be sustained without any down-hole complications.

2.7.1 Drilling of Exploratory well

To explore hydrocarbon in sub-surface, an oil well is drilled by deploying a drill rig. In the process of

exploratory drilling, drilling fluid is used to lift the cutting from the hole to the surface. Drilling fluid is

formulated by earth clay and barites. Various types of bio-degradable polymers are also added to

maintain the specific parameters of the mud. After completion of production casing the well is tested to

determine & analyze various parameters of producing fluid.

Where a hydrocarbon formation is found, initial well tests are conducted to establish flow rates of oil &

gas and formation pressure along with other reservoir parameters. These tests may then generate oil,

gas and formation water. On completion of testing, the well would be declared oil / gas producer or dry.

Exploration, of oil & gas process may encounter various hazards such as well active situation (kicks),

blowouts, H2S situation etc. They are discussed in brief as follows.

Well Kick Situation

While drilling, if the formation pressure exceeds the hydrostatic pressure exerted by the drilling

fluid, formation fluids break out in to the well bore. This is called kick. Primary means of well

control is to have sufficient over-balance, over formation pressure. For some reason if an

unexpected over-pressurized formation is encountered while drilling and if the well control

situation arises, rig is equipped with equipment to control this situation.

Blowout Situation



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1) Crown Block

2) Catline Boom and Hoist

Line

3) Drilling Line

4) Monkeyboard

5) Traveling Block

6) Top Drive

7) Derrick or Mast

8) Drill Pipe

9) Doghouse or drillers shack

10) Blowout Preventer

11) Water Tank

12) Electric Cable Tray

13) Engine Generator Sets

14) Fuel Tanks

15) Electrical Control Room

16) Mud Pump

17) Bulk Mud Components

Storage

18) Mud Pits

19) Reserve Pits

20) Mud Gas Separator

21) Shale Shakers

22) Choke Manifold

23) Pipe Ramp

24) Pipe Racks

25) Accumulator

FIGURE-2.2 DRILLING RIG SKETCH



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Uncontrolled “well control situation” eventually leads to a blowout. Blowout can cause a partial

or total destruction of drilling rig. Blowouts are often associated with hydrocarbon spill followed

by fire.

Well Control

This set of equipment is called “Blowout Preventers (BOP)”. Blowout Preventer consists of,

“Annular Preventer”, which can generally close on any size or shape of tubular in the well bore

and closes the annular space between drill string and casing. Another type of blowout preventer

is a “Ram Preventer”. Ram preventers are of two types i.e., Pipe Rams and Shear Rams. Pipe

rams also close the annulus between drill string and casing, but they have a fixed size. As such

a specific pipe rams can be closed on a specific size of pipe.

Shear rams are generally the last choice of preventer to be operated as they shear drill string

and shut off the well bore. After determining the existing formation pressure and other geological

complexities from the seismic data, appropriate BOP will be used as per standard oil field

guideline for the same.

2.7.2 Proposed Hole Size / Casing Programme

The wells will be of “Slim Hole Design”. The wells will be drilled vertically to different depths based

on the “target” depth. It is to be noted that the figures given in the table below are approximate

and subject to change as the drilling proceeds.

2.7.3 Surface Testing & Flaring

ONGC will conduct vertical flaring at all the sites, in case the presence of hydrocarbon is

encountered. A flaring stack with burner and adequate stack height will be provided.

Approximately, the duration of the test is around 2-3 days. Temporary test separators with all

control facilities for flow metering will be provided. Testing facilities will be available at drilling rig



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for separation of liquid phase and burning of all hydrocarbons during testing. The test flare boom

will be located at a distance from the drilling rig.

2.8 Details of Project Utilities

2.8.1 Site Preparation

On identification of the proposed each well site, reconnaissance survey will be done to locate suitable

land on temporary lease basis. Land clearance for site construction at each drilling site will be kept to a

minimum practicable in order to safely accommodate the facilities.

Earth moving equipment typically a bull dozer armed with a grader blade / ripper teeth and scoop bucket

will be used for the leveling / grading and excavating work. Where possible topsoil will be cleared and

stored for later reinstatement purposes by piling it along the boundary of the site. The natural contours

will be worked on to minimise off-site disposal of excavated earth. The site area (except the pit areas)

will be provided with hard-standing by providing a layered base of coarse aggregate covered with

moorum. This is done to provide sufficient load-bearing capacity to enable all construction and drilling

operations to be executed safely.

2.8.2 Approach Roads

The approach road to each well sites will need to be constructed/ upgraded to provide access for the

drilling equipment and construction machinery and material, supply vehicles, passenger vehicles etc. In

general, it is intended to make maximum use of the existing infrastructure by strengthening the roads with

the consent of the local administration and the concerned regulatory authorities. This would result in an

added advantage to the local community. In case new roads are to be made, compensation for right of

way will be provided. The choice to leave these newly constructed roads or to restore them back to

original land use condition will depend on the requirements of the local authorities.



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2.8.2.1 Installation of Facilities

Site construction would include the impermeable layer lined drilling fluid, drill cuttings, waste and water

storage pits, foundations for the drilling rig and accessories, inter-connecting drains, secure storage

provision for chemical, oil and waste oil, portable-cabins and a sewage treatment system (septic tank and

soak away pits and piping). A ground level flare pit arrangement will be made for flaring purpose.

The mobilization of the each well site involves transportation of drilling rig in modules and erected by

means of mobile cranes. The well site equipment’s are designed as modular / skid mounted type, which

facilitates quick demobilization and re-mobilisation. The installation of the well site equipment / facilities

involves about 50 trailer loads spread over 10 days. Once the site is prepared, drilling equipment, supplies

and drilling personnel will be mobilized and the drilling rig will be erected.

The salient features of the well site facilities are detailed below.

Earthwork

The each well site area will be fenced by high barbed wire. The drilling rig will be positioned

almost in the middle of this area. Typically, a depth of 1.0 or 1.5 m is excavated around the

prospecting drilling location. Excavation work shall be carried out under the permit-to-work

system and in such a manner that the collapse of sidewalls is precluded. The foundations for the

drilling rig and accessories, inter-connecting drains, secure storage provision for chemical, oil

and waste oil, porta-cabins and a sewage treatment system (septic tank and soak away pits and

piping) waste and water storage pits will also be set up. Appropriate fencing and sign boards will

be provided to prevent persons and livestock from accidentally falling into an excavation pit.



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Surface Drainage

The proposed project sites and camps will have an adequate drainage and wastewater

conveyance system so that all wastewater are contained and can be disposed as per the Gujarat

State Pollution Control Board (GPCB) discharge norms.

The drilling rig location will be connected with paved drains to the lined drilling fluid collection

pits. Surface drains will be adequately graded and maintained and kept debris free to ensure

quick disposal of their contents. Bunds will be sized so that they can contain surface runoffs for

limited period.

Fuel & Chemical Storage Area

The fuel (Diesel) will be received in bulk quantity through road tankers and stored in above

ground steel diesel tanks. The tanks will be constructed, operated and maintained as per the

requirements of the Explosive Rules and all the statutory licenses will be obtained. The tank farm

area will be provided with secondary containment of adequate capacity to impound any

accidental leaks.

Chemicals will be stored on a paved platform with kerb walls and protected against weather

through an impervious covering. Separate storages are earmarked for liquid and solid chemicals.

All the storages are identified with tags and sign boards. All required safety precautions such as

display of the MSDS, provision of fire extinguishers are followed.

Waste Oil collection, Storage & Disposal System

Waste oil of about 150-200 liters/month from pumps or other machinery will be trapped and

manually collected and stored in a paved dedicated waste oil storage area. The storage area will

be provided with paved flooring, containment bunding and covered roofing. The storage facility



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shall be designed based on the CPCB guidelines for Hazardous waste Storage. The waste oil

will be collected and handed over to GPCB and MoEF&CC authorized waste oil recyclers at the

end of the drilling campaign.

Spill Containment System

Containment systems and oil traps will be provided to trap any escape of oil before it can leave

the drilling site. All potential sources of spillage will be equipped with drainage facilities / drip

pans / spill collection kits in order to contain spills. Drains and bunds will be sized to contain

surface runoffs for limited period and any oil detected in the drains will be manually soaked using

sorbent materials.

Water & Drilling Fluid Storage Pit

The water storage pit contains the water used for preparing drilling fluid. The drilling fluid storage

pit will collect all the wastewater, which come from the drilling operations. The wastewater

present in the waste pits will be recycled and reused during drilling phase. Whereas, the residual

wastewater from the drilling operation will be collected in waste pits for solar drying. The pit will

be lined with polyethylene propylene sheet and the overlaps welded together with the edges

bought over the rim and tucked into the soil. At the end of the drilling phase, the liquid fraction

of the waste drilling fluid will be allowed to evaporate and the pit is filled with soil and capped with

compacted moorum layer.

Drill Cuttings Disposal Pit

During drilling operations, approx. 500 m3 per well drill cutting are expected to be generated from

each well depending on the type of formation and depth of drilling. Cuttings will be collected and

disposed off in an environmentally safe manner. The cuttings disposal pit will be similar in

construction to the wastewater pit. Typically the pit (will be 2 nos of 30’ x 33’ x 5’ deep, 1 nos of



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38’ x 33’ x 5’ deep and 1 nos of 23’ x 20’ x 5’ deep) will be lined with polypropylene liner. The

cuttings disposal pit will be placed within the drilling lease area to prevent the transport of waste

mud and cuttings from the drilling site to another area to prevent any spillage on the other areas.

Domestic Sewage Treatment & Disposal System

The domestic sewage generated from the each well site operations will be disposed off in a septic

tank – soak pit system. The septic tank will conform to the IS design specification. The overflow

from the septic tank will be led into series of soak pits for sub-surface disposal.

Drilling Fluid Circulation

The drilling fluids circulation system consists of several items of equipment. The mud pump takes

in mud from the mud tanks and sends it out a discharge line to a standpipe. The standpipe is a

steel pipe mounted vertically on one leg of the derrick. The mud is pumped up the standpipe into

a flexible reinforced rubber hose called the Kelly hose. The Kelly hose connected to the swivel;

goes down the Kelly, drill pipe and drill collars and exits at the bit. The mud then does a sharp

U-turn and heads back up the hole in the annulus. The annulus is the space between outside of

the drill string and the wall of the hole. Finally, the mud leaves the hole through a steel pipe called

the mud return pipe and falls over a vibrating screen like device called the shale shaker. The

mud containing cuttings is screened out of the shaker. The mud drains back into the mud tanks

and is recycled back into the well via the mud pump, while the drill cuttings which are inert

materials of shale, sand, and clay fall into the lined waste pits. Once the mud is cleaned, it is

pumped down the drill string again. The drilling fluids left over at the end of the particular well,

which can’t be further reused, will be discharged into the lined waste pits and dried. The pits will

be provided with HDPE liners to maintain integrity and prevent any leakage. The drill cuttings

cut by the drill bit are removed from the mud by the shale shakers and other solids removal

equipment and transferred to the waste pits. The drilling fluid circulating system at rig is

essentially a self contained, closed system, shown in Figure-2.3



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Role of Drilling Fluids

Drilling fluid serves the following essential functions:

The removal of drilled solids (i.e. cuttings) from the bottom of the hole and their transport to

the surface for separation from the mud;

Lubrication and cooling of the drill bit and string;

Deposition of an impermeable cake on the well bore wall to seal the formation being drilled;

Suspension of drilling cuttings in the fluid during the interruption of drilling; and

Countering the natural formation pressures and preventing uncontrolled flow of fluid from the

formations.

The role of the drilling fluids in pressure control is especially important. If the drill bit penetrates

a formation containing oil, gas or water under pressure these fluids are prevented from flowing

into the borehole by ensuring that the drilling mud is of sufficient density to counter the natural

formation pressures. The density of the mud can be increased by the addition of barite weighting

material. Bentonite is employed to improve the rheological properties and enable the drill cuttings

to be transported from the hole while drilling and also be suspended in the fluid while the drill bit

is being changed. The barite used in the drilling mud would be as per API standard specifications.

Water based drilling fluids, which are of an environmentally acceptable nature with regards to

current Indian legislation, will be used. The water based drilling fluid will be non-hazardous in

nature.



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FIGURE-2.3 DRILLING FLUID CIRCULATION SYSTEM AT TYPICAL RIG



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2.9 Post Drilling Operations - Abandonment and Restoration

2.9.1 Demobilization & Decommissioning

Well Capping - Removal of Equipment and Materials

In the event that economic quantities of hydrocarbons are found, the well will be suspended with

a wellhead/X-mass tree in place, but all other equipment and materials will be removed from the

site.

All empty drums, wastes, used and unused drilling fluids, fuel and lubricants will be removed

from the drilling site. Water supply and effluent discharge hoses and associated equipment will

be removed. The access road(s) would be either left behind or reinstated based on the needs of

the local authorities.

Restoration of Cutting Containment Area

At the conclusion of well testing at each drilling site, the spent drilling fluids will be dewatered by

flocculating the contents and allowing the water phase to evaporate away. All solids & liner will

be buried in a secured lined pit and covered with soil and left onsite. The cutting mud is inert and

with appropriate lining of the pit in place it does not pose any potential for soil or groundwater

contamination. ONGC will follow a well laid site restoration plan. Tree plantation will be done on

the closed pits to restore the original soil conditions. At all the sites the pits are filled with the

black cotton soils or red soils which is available at shortest distance. Filling and plantations are

handed over to the contractors with close watch of ONGC officials.

2.9.2 Restoration of Well Sites

Decommissioning upon Abandonment



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In the event that economic quantities of hydrocarbons are found, the well site will be closed as

detailed above. In the event that no economic quantities of hydrocarbons are found, a full

abandonment plan will be implemented for the drilling sites.

The actions outlined above would apply to decommissioning upon abandonment as well, but

abandonment would be more permanent. All concrete or steel installations would be removed to

at least 1 m below ground level so as to ensure that there are no protruding surface structures.

In the unlikely event that soil is found contaminated, measures would be taken to remove or treat

appropriately all contaminated topsoil to promote its remediation. This is as per the ONGC’s

Restoration SOP.

The overriding principle being that the environment should, with time, be reinstated to broadly its

original condition. Until such time as this is achieved, ONGC would actively manage the

reinstatement process.

2.9.3 Traffic Volumes

During the civil operations earth moving equipment will be working on the access road and the

well location. It is anticipated that there will be an average of 5 truck movements a day to cater

the site preparation for an average period of about 20 days.

Prior to and after the drilling operation, when building the rig or rig move, up to 80 heavy

truckloads over a period of 4-5 days are envisaged.

During the drilling operation, supply truck movements are estimated on an average of eight to

five per day. Small vehicles movements are used mainly for transport of personnel, visitors etc.

which might be as much as 10 per day.



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ONGC will engage in constructing compacted approach roads without black topping to all well

locations and camp sites. Though this will not cause any changes in topography, the dust

generation will be less than any other village roads. The same roads can be used by the villagers

after completion of the Exploration activities.

2.10 Sources of Pollution

2.10.1 General

The various types of pollution from the proposed project operations are:

Water Pollution;

Air Emission;

Solid Waste Generation & disposal ; and

Noise Generation.

Exhaust gases from DG sets, wastewater, drilling wastes and noise from the drilling operations

are the major sources of the pollutants generated during the proposed drilling operations which

is temporary activity lasting for maximum of 3-4 months at each of the well locations.

2.10.2 Wastewater Generation and Disposal

The water will be required during the drilling rig is mainly meant for drilling mud preparation and

for domestic purposes. Thus, wastewater during this phase will comprise of drilling wastewater

and domestic wastewater.

The proposed project sites and camps site will have an adequate drainage system so that all

wastewater are contained and disposed as per the CPCB Standards. Means will be provided to

trap any escape of oil before it can leave the site. Surface drains will be adequately graded and



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kept debris free to ensure quick disposal of their contents. Minor quantity of wastewater would

be generated from cleaning operations carried out at the rig. About 5 m3/day of wastewater is

expected.

All wastewater streams except sewage will be directed to a 1.5 mm HDPE lined pit. Wastewater

collected in the pit will be solar dried.

Domestic Wastewater

Sewage generated from the camps would be discharged and treated in septic tanks. The

supernatant from the septic tanks will be passed through soak pits into the ground.

2.10.3 Air Emissions

During Exploration of oil & gas, air pollutants are emitted by the diesel engines that power the

drilling equipment. These engines release particulate matter that can contain heavy metals,

volatile organic compounds and polycyclic organic matter. They also emit sulphur dioxide, oxides

of nitrogen which contributes to smog formation. The vehicular movement associated with the

drilling activities is also an important cause for the dust pollution.

The predominant air emissions from the proposed project operations are gaseous emissions,

viz., sulphur dioxide, oxides of nitrogen and hydrocarbons.

Each power generator will have the adequate stack height for easy dispersion of gaseous

emissions. The height of the DG exhaust stack will be about 6.8 m (including the height of the

trailer from the ground).

Traces of Natural gas will be flared during the well testing phase for short period. The test flaring

will result in temporary emissions of CO2, water vapours, NOX and other trace gases in case of



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natural gas flaring and additionally particulates in case crude oil is flared. It is assumed that the

occurrence of SO2 in the flare gas would be in traces or negligible.

2.10.4 Solid Waste

The proposed project operations generate drill cuttings. The minor wastes include sanitary waste,

domestic waste and waste oil from lubricating system.

2.10.4.1 Drilling Mud

The drilling mud will be re-circulated and reused to maximum possible extent through its mud

recycling system. Maximum amount of drilling mud attached to the drill cutting is separated by

Solid control System such as Shale Shaker, clay shaker and will be recycled during the drilling

process. However, only a portion of the non-usable mud at the end of the drilling would be

discharged. The drilling mud will be collected in lined pit and solar evaporated.

2.10.4.2 Drill Cuttings

Drilling cuttings are worn out rocks from subsurface formations that are generated during drilling

operations. The drill cuttings are conveyed to the surface, suspended in the drilling fluid (drilling

mud). The drill cuttings are separated in the shale shaker from the drilling mud and are stored in

an impervious 1.5 mm HDPE lined pit. The particle size varies from coarse particles of less than

1mm diameter to few centimeters. Drill cuttings are encapsulated by a thin layer of adhering mud.

The drill cuttings will be washed thoroughly and the wastewater generated will be collected in

HDPE Lined pit at site and will be solar dried.



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2.10.4.3 Waste Pit Details

Typical sectional view of the drill cutting and drilling mud collection pit is presented in Figure-2.4

2.10.4.4 Used / Spent Oil

Used / spent lubricating oil from pumps or other machinery would be trapped and manually

collected and stored in a paved dedicated waste oil storage area. Approximately 150-200

liters/month of used/ spent oil would be generated from a drilling operation. Stored waste oil

would be disposed off to CPCB & MoEF registered used / spent oil recyclers.

2.10.4.5. Drilling Mud and Drill Cuttings Analysis

The drill cuttings & the drilling mud at each location will be tested to ensure it meets the

requirement of MoEF&CC guidelines for disposal of drill cuttings and drilling fluids for onshore

operations. The analysis carried out on spent drilling mud / cuttings during the previous drilling

campaigns by ONGC in other parts of the country have reported LC50 in excess of 30,000 mg/l.



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FIGURE-2.4 TYPICAL SECTION VIEW OF DRILLING CUT AND DRILL MUD COLLECTION PIT

2.10.5 Noise Levels

The major noise generating sources are DG sets, pumps at drilling rig and other equipment of drilling rig

would contribute to continuous noise. Typically, the noise generating sources for the drilling activity are

provided below (in the immediate vicinity):

Diesel Generator : 90 to 95 dB(A)

Pumps at the Rig : 85 to 90 dB(A)

Miscellaneous : 80 to 85 dB(A)

Control Room & Quarters : 50 to 60 dB(A)

Noise is not considered to be a potential threat since the drilling sites will be selected keeping in view that

there are no settlements in close proximity to the drilling site.



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2.11 Qualifications, Skills and Training Practice

a) Qualification

Jobs requiring specific qualifications and certificates e.g. welding, driving of vehicles, electrical

work, crane operation, fork lift & bulldozers operation should be carried out only by persons

having the required qualifications and certificates. The certificates should be properly checked

for adequacy and a copy of the same should be available for verification by ONGC personnel.

b) Skills

Certain jobs e.g. operation of cranes and other mechanical equipment, erection of scaffolding

need required skills and persons deployed should be checked for possession of adequate skills

and experience in carrying out such work.

c) Training

All required HSE related training e.g. safe evacuation during emergencies, permit to work

requirements, proper use of personal protective equipment, should be provided by the contractor

HSE supervisor. The training contents should be discussed with the ONGC HSE personnel.

d) Personal Protective Equipment (PPE)

No personnel will be allowed into the well site if the required PPE is not used. Adequate stock of

required PPE will be available and distributed whenever needed. The PPE requirements are hard

hat and safety shoe and those working in the drilling rig, overalls, gloves, safety glasses, nose

masks when needed) and ear-muffs. Personnel working at height (during maintenance / erection)

will need to use safety belts securely anchored.



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e) General HSE Requirements

The general HSE requirements of ONGC which is strictly complied with by all ONGC and contract

employees are enumerated below.

f) Vehicle Movement

The speed limit for vehicles is 10 kms/hr in village area and near to schools and in construction

area. On tar road maximum speed is restricted to 35 km/hr and on highway speed should not be

more then 60 km/hr for heavy vehicles and 80 km/hr for light vehicle

g) No Smoking Regulations

Smoking is strictly prohibited in all the areas in the site

h) First Aid Center

A first aid center shall be located at the construction site. The service of a doctor shall also be

available all the time in the first aid center.

i) Permits

Type of permits agreed should be obtained wherever required. Conditions and precautions

mentioned in the permit should be strictly followed.

j) Fire Extinguishers

Temporary fire extinguishers shall be readily available at convenient locations for use during any

fire emergencies.



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All persons working in the contract should be above 18 years of age and no child labour will be

engaged in any job at any time.

k) Safety Seat Belts

All the vehicles used for construction purpose should be provided with safety seat belts. No

vehicles are allowed inside the site without safety seat belts.



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Chapter 3

Description of Environment



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3.0 Introduction

This chapter illustrates the description of the existing environmental status of the study area with

reference to the prominent environment attributes to assess environmental impacts from the proposed

project activity.

3.1 Baseline environmental Study

The study area was determined through collection of samples followed by quantifying environmental

indicators of air, noise, water, land, ecology and socio-economic status. The baseline environmental

quality has been determined for Summer Season by following guidelines prescribed in MoEF & CC, EIA

notification and ToR issued to the ONGC.

The baseline environmental qualities for the proposed exploratory drilling locations have been assessed

for the following environmental components, which are most likely to be influenced by the drilling activity:

Geology

Hydrogeology

Seismicity

Land Environment

Ambient Air Quality

Meteorological conditions

Noise levels

Water quality (Surface +Ground water)

Soil quality

Biological and

Socio-economic studies.



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The primary baseline environmental quality for the EIA is assessed through field studies within the impact

zone for various components of the environment, viz. air, noise, water, Soil and socio-economic.

3.2 Geology

The Cambay basin is a proven and rich petroleum province and has generally favourable combination of

source sediments, reservoir rocks, regional seals and traps. The Cambay shale is the main source rock

sequence in the basin along with minor contributions of oil from Kalol, Tarapur and Olpad formation. The

fluvio-deltaic sediments of the Kalol and Ankleshwar formations of upper Eocene age are the main

reservoirs. Oil trapped in these upper Eocene reservoirs are effectively sealed by the Tarapur/Kanwa

shales of upper Eocene-Oligocene age.

A favourable combination of reservoir-source-cap in the Eocene –Oligocene sequence of the basin

formed essentially one petroleum system. This can be divided into two sub systems depending on its

development in the Northern and Southern part of the basin.

1. The Cambay shale-Kadi/Kalol Tarapur petroleum system in the northern part of the basin

(Cambay-Tarapur and Ahmedabad-Mehsana Blocks, and

2. The Cambay shale – Hazad-Kanwa petroleum system in the southern part of the basin (Narmada

and Bharuch Jambusar blocks).

3.3 Hydrogeology

The hydrogeological studies were carried out to understand the local geology, geomorphic features,

drainage network, aquifer characteristics and yield of water along with various components controlling

the hydrogeological regime. Hydrogeology maps of Mehsana district of Gujarat is given in Figure-3.1.

Precambrian hard rocks, semi-consolidated Mesozoic and tertiary formations and unconsolidated

quaternary alluvial deposits form multi-layer aquifer system in the district. Groundwater occurs both under

phreatic and confined conditions, however its development is restricted depending upon the aquifer

geometry and yield characteristic of individual aquifer and/or ground water quality of the formation water.

Occurrence of groundwater can be divided in two groups.



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Figure-3.1 Hydrogeology Map of Mehsana District Of Gujarat

a) Ground water in fissured formation (Hard rock): The north-eastern part of the district mainly in

Satlasna taluka is occupied by meta sediments and Post Delhi intrusives. The occurrence and movement

of ground water is governed by secondary porosity i.e. thickness and extent of weathering and size&

interconnections of fractures/joints. These formations generally don’t form good aquifer system. The

depth of dugwells range from 15-30 mbgl and of borewells from 100-120 mbgl. Depth to water level in

the dug wells varies from 5 -14mbgl and in borewells from 15to 60 mbgl. The yield of wells range from

30-120m3 /day with an average of 75m3 /day.



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b) Groundwater in porous formations (Sedimentaries): Major part of the district is underlain by post

Miocene alluvium and older sedimentary formations. These sediments are mainly consisted by Coarse

sand, gravel, kankar, silt, clay and clay stones. Groundwater occurs both under phreatic and confined

conditions in arenaceous horizons within sedimentaries. The occurrence and movement of groundwater

is mainly controlled by intergranular pore spaces.

3.3.1 Ground Water Resources

The main source of ground water recharge is by the rainfall by direct percolation to the zone of saturation.

A significant part of the rainfall is lost as runoff from area while a limited percentage of rainfall therefore

reaches zone of saturation and becomes the part of ground water storage after meeting the evaporation

and evapo-transpiration losses. There is also ground water recharge from the return flow of irrigation

water from dug wells and tube wells operated by the cultivators and from canals.

The ground water levels measured in the study area during the primary survey:-

i) Major water bearing formations: Groundwater occurs in unconfined to confined condition

in Quaternary alluvium and under unconfined condition in granite gneiss in limited area.

ii) Pre-monsoon water level: 2.15 to 34.35 mbgl.

iii) Post-monsoon water level: 1.10 to 33.77 mbgl.



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Fig 3.2: Ground water Pre Monsoon level map of Mehsana District



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Fig 3.3: Ground water Post Monsoon level map of Mehsana District

3.4 Seismicity and Floods:

Study Area is categorized in the seismic zone III, which is classified as having a fairly high probability of

earthquake shocks measuring 5 or 6 on the Richter scale, low probability of shocks of 6 or 7 on the

Richter scale and Seismic Zone IV which is referred as High damage risk Zone.

Source: Seismic Map of Gujarat from Institute of Seismological Research (Government of

Gujarat.http://www.isr.gujarat.gov.in/Seismic_Zoning_Gujarat.shtm)



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Figure-3.4 Seismic Zone Map of India

Fig 3.5 : Seismic Zone III of the Study area



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3.5 Land Environment

3.5.1 Topography:

The terrain of the district is almost flat plain except a small hilly portion in the eastern part with an elevation

ranging from 57 m to 370 m above MSL. The general slope of this district is from NE to SW. The mining

lease falls in central, SW and southern part of the district which has almost flat terrain.

3.5.2 Land Use Studies

Studies on land use aspects of eco-system play important roles for identifying sensitive issues, if any,

and taking appropriate actions for maintaining the ecological balance in the development of the region.

The objectives of land use studies are:

To determine the present land use pattern;

To analyze the impacts on land use due to proposed project activities in the study area; and

To give recommendations for optimizing the future land use pattern vis-a-vis growth of

proposed project activities in the study area and its associated impacts.

3.5.2.1 Methodology

The land use/land cover maps of the study area were obtained from Bhuvan outreach portal of National

Remote Sensing Centre, ISRO. These Land Use Land Cover maps were developed from LULC Vector

data of 2005-06, Multi-temporal satellite data of 2011-12 from Resourcesat-2 LISS III in the scale of

1;50,000. The various steps involved in the study are preparatory field work, field survey and post field

work. The Land Use Land Cover maps were prepared based on the classification system of National

standards. The land use pattern of the Mehsana District is shown in Figure 3.6 The main interpreted land

use/land cover classes of the Mehsana District and their respective areas are given in Table 3.1.



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Figure 3.6: Land Use pattern of Mehsana District.



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Table: 3.1 Land use classification and area of Mehsana District

S.NO Level – 1 Level - 2 Area

(Sq.Km)

Area

(Hectare)

1 Built-up Built-up, Urban 39.7 3970

Built-up, Mining 0.56 56

Built-up, Rural 49.44 4944

2 Agriculture

Agriculture, Plantation 1.98 198

Agriculture, Crop land 2840.89 284089

Agriculture, Fallow 117.26 11726

3 Forest Forest, Deciduous 52.19 5219

Forest, Scrub Forest 4.83 482

4 Wastelands

Barren/unculturable/Wastelands,

Gullied/Ravinous Land

42.1 4210

Barren/unculturable/Wastelands, Sandy

area

0.05 5

Barren/unculturable/Wastelands, Scrub

land

109.82 10982

5

Water bodies

Wetlands/Water Bodies,

River/Stream/canals

58.01 5801

Wetlands/Water Bodies, Coastal Wetland 5.45 545

Wetlands/Water Bodies,

Reservoir/Lakes/Ponds

20.73 2073

TOTAL 3343.00 334300

The above table indicates that, the 84.98 % of land comprises of Agriculture, Crop Land ( 284089 hectare

), 3.51 % is Agriculture, fallow ( 11726 hectare ), 3.29 % is scrub land (10928 hectare), followed by water

bodies (8419 hectare), built up land (8970 hectare) and water bodies (5701 hectare)



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3.6 Meteorology

The meteorological data recorded during the study period is very useful for proper interpretation of the

baseline information as well as for input to prediction models for air quality dispersion.

On site monitoring was undertaken for various meteorological parameters in order to generate the site

specific data. The central monitoring station (CMS), equipped with continuous monitoring equipment to

record wind speed, wind direction, temperature, humidity and rain fall was set up at the top of the building

at a height of ~ 5.0m above the ground level. The methodology adopted for monitoring surface

observations was as per the Standard norms laid down by the Bureau of Indian Standards (IS:

8829:1978) and IMD.

3.6.1 Meteorological data recorded at study area

The meteorological parameters was recorded at Rupal on hourly basis during the study period from the

date 27th April 2018 to 27th July 2018 consist of parameters like Wind speed, Wind direction, Humidity

Temperature and total rainfall. The maximum and minimum values for Temperature & Humidity are

presented in Table 3.2.

TABLE – 3.2: Summary of the Meteorological Data Generated In Study Area

Month

Rupal

Temp. (0C) Relative Humidity (%) Rainfall (mm)

Max Min Max Min

April 2018(27th to 30th) 40.1 28.2 60 34 0

May 2018 40.3 28.9 62 30 0

June 2018 37.4 27.4 87 45 30

July 2018(1st to 27th) 35.5 25.4 94 63 60

27th April 2018 to 27th July

2018 40.3 25.4 94 30 90

Source: ABC Techno Labs India Private Limited



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The summary of the wind pattern for the study period is listed in Table-3.3. The graphical presentation

of the same illustrated from Figure-3.7 (a) to 3.7 (b).

TABLE – 3.3: Summary of Wind Pattern at Rupal

Month First Predominant

Wind Direction Second Predominant Wind

Direction Average Wind Speed

(m/s)

April 2018(27th to 30th) NW W 1.3

May 2018 NW W 1.0

June 2018 NW SW 1.2

July 2018(1st to 27th) NW W 1.1

27th April 2018 to 27th July

2018 NW W 1.1

Figure: 3.7 (a): Windrose Diagram for April-18, May -18, June 18 & July 18 at Rupal



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Figure: 3.7(b): Windrose Diagram from April 27TH -2018 to July 27th 2018 at Rupal

3.6.2 Secondary Data from Indian Meteorological Dept., (IMD), Ahmedabad

The nearby India Meteorological Department station that is generating meteorological data nearest to the

study area is IMD, Ahmedabad. Hence, secondary information on meteorological conditions has been

collected from Ahmedabad IMD station. Indian Meteorological Department at Ahmedabad regularly

monitors wind direction, wind speed, relative humidity, temperature and rainfall at 08.30 hours and 17.30

hours every day. Wind rose diagrams (1971-2000) collected for IMD, Ahmedabad is shown in Figure –

3.8(a) & 3.8(b).



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Figure 3.8(a): Windrose diagrams for the month of April, May, June & July - IMD, Ahmedabad

(1971-2000)



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Figure 3.8(b): Annual Windrose diagrams from IMD, Ahmedabad (1971-2000)

The month wise mean maximum & minimum values of temperature, relative humidity and rainfall data

collected from IMD, Ahmedabad for the period 1971-2000 are presented in below Table – 3.4.

Table 3.4: WEATHER DATA FROM IMD, AHMEDABAD (1971-2000)

Month Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Max- Temp (C)

28.1 30.5 35.7 39.7 41.6 38.7 33.5 32.0 33.8 35.7 32.8 29.4

Min Temp (c)

12.0 14.0 19.1 23.7 26.5 27.3 25.7 24.9 24.3 21.3 16.6 13.2

RH (%) 49 42 35 39 45 60 77 79 71 54 47 49

Rainfall (mm)

1.9 1 0.5 2.7 10.2 95 281 234 96 12 4 0.8

Source: IMD, Ahmedabad



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Figure 3.9: Monthly Average Maximum and Minimum Temperature in ◦C

Figure 3.10: Monthly Average Rainfall in mm and Relative humidity in %

0

5

10

15

20

25

30

35

40

45

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Tem

p°C

Month

Temperature Max- Temp (C)

Min- Temp (C)

0

50

100

150

200

250

300

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Rai

nfa

ll (m

m)

Month

Rainfall and Relative Humidity RH (%)

Rainfall (mm)



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3.7 Ambient Air Quality

A reconnaissance survey was undertaken to identify the sampling locations to establish baseline status

of Ambient Air quality in the study area. The sampling stations were selected based on guidelines of air

monitoring network siting criteria such as:

Topography of the study area

Persistence of wind direction and speed

Representation of regional background

Populated and sensitive areas

Location of industries and their emission magnitude

Screening of maximum ground level concentrations and distances of their likely occurrences as

per climatological normal

Representation of valid cross-sectional distribution in down-wind direction.

3.7.1 Selection of Sampling Locations

The ambient air quality around the location within 10 km radius was monitored at eleven (11) stations. To

establish the baseline monitoring of air quality in the study area during summer season; Ambient Air

Quality Monitoring stations eleven (11) were selected using network design criteria and monitored as per

CPCB guidelines.

As per NAAQS (2009) the pollutants viz., particulate matters (PM10 and PM2.5), sulphur dioxide (SO2),

nitrogen dioxide (NO2), carbon monoxide (CO) and ammonia (NH3) were stipulated parameters for air

quality monitoring. All the parameters were monitored on 24 hourly while CO was monitored on hourly

basis. Standard analytical procedures were used for analysis and quantification of air quality parameters

and the details are given in Table 3.5 &3.6. The photographs show in sampling stations/locations are

given in the Figure 3.11.

3.7.2 Frequency and Parameters for Sampling

Ambient air quality monitoring was carried out at a frequency of two days per week at each location for

continuous three months. The baseline data of air environment was generated for the parameters namely

Particulate Matter size less than 10 µm (PM10), Particulate Matter size less than 2.5 µm (PM2.5), Sulphur



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dioxide (SO2), Oxides of Nitrogen (NOx), Carbon Monoxide (CO), Volatile Organic Compounds (VOCs),

Hydrocarbon (Methane& Non-Methane) and Hydrogen Sulphide (H2S).

3.7.3 Instruments used for Sampling

Respirable Dust Samplers APM 460 BL of Envirotech, Fine Particulate Samplers APM 550 of Envirotech

& Combo PM10 & PM 2.5 sampler AAS 271 of Envirotech were used for monitoring the Particulate matter

PM10 & PM 2.5. The Gaseous pollutant samplers AAS 109 of Ecotech or APM 411 along with APM 460

Envirotech were used for sampling of gaseous parameters like SO2, NOx, H2S, VOCs & HC. Carbon

Monoxide was measured using electro chemical sensor method. The instruments used for monitoring are

periodically calibrated every year or after in case of any repair.

3.7.4 Sampling and Analytical Techniques

The sampling and analytical techniques used for the monitoring of Ambient Air quality is given in Table

3.5. The power supply for the operation of AAQ instruments were utilized from either residential or

commercial buildings nearest to each AAQ station.

TABLE – 3.5: Techniques used for Ambient Air Quality Monitoring

S.No Parameter Technique Technical Protocol Detectable

Limit

1 Particulate Matter of size

less than 10 µm (PM10)

Gravimetric method IS 5182 Pt.23 : 2006

(Reaff. 2017) 5 g/m3

2 Particulate Matter of size

less than 2.5 µm (PM2.5)

Gravimetric method EPA- 40 Appendix L

To CFR PART 50 5 g/m3

3 Sulphur dioxide (SO2) Improved West and Gaeke IS 5182: Part 2:2001

(Reaff. 2017) 5 g/m3

4 Oxides of Nitrogen (NOx) Modified Jacob &

Hochheiser

IS 5182: Part 6:2006

(Reaff. 2017) 5 g/m3

5 Carbon monoxide (CO) Non Dispersive Infra Red

(NDIR) Spectroscopy

IS 5182:Part 10 :1999

(Reaff. 2014) 0.1 mg/m3

6 Hydrogen Sulphide (H2S) Colorimetry Method IS 5182: Part 7:1973

(Reaff.2014) 5 µg/m3

7 VOCs & BTX GC-MS/MS ABCTL/INS/SOP/035 1 µg/m3



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8 Methane HC GC FID ABCTL/INS/SOP/038 0.1 µg/m3

9 Non-Methane HC GC FID ABCTL/INS/SOP/038 0.1 µg/m3

Ambient Air Quality Monitoring (AAQM) stations were set up at eleven (11) locations with due consideration

to the above mentioned points. The Ambient Air Quality monitoring locations are given in the Table-3.6.

Monitoring Photographs enclosed as Annexure II.

TABLE – 3.6: DETAILS OF AMBIENT AIR QUALITY MONITORING LOCATIONS

Code Location Coordinates Description of AAQ Station

AAQ1 Bilodra

23o31’24.99” N 72o38’59.62” E

Rural Settlement, Top of Bilodra Panchyat Office

AAQ2 Ajol

23o30’32.26” N 72o41’16.2” E

Rural Settlement, Top of Ajol Panchyat Office

AAQ3 Ridrol

23o27’32.55” N 72o40’31.41” E

Rural Settlement, Top of Ridrol Panchyat Office

AAQ4 Fatepura

23o55’56.22” N 72o38’12.9” E

Rural Settlement, Near Fatepura Primary School

AAQ5 Kherva

23o32’37.03” N 72o26’38.79” E

Rural Settlement, Top of Kherva Panchyat Office

AAQ6 Lagnaj 23o26’53.30” N 72o29’50.84”E

Rural Settlement, Top of Residential building

AAQ7 Irana 23o18’30.43” N

72o23’18.9” E Rural Settlement, Near Ram

Pir Temple

AAQ8 Rupal 23o41’4.63” N 72o20’36.18” E

Rural Settlement, Top of Milk Dairy

AAQ9 Ambaliyasan 23o27’9.35” N 72o25’26.66” E

Rural Settlement, Top of Residential building

AAQ10 Linch 23o29’44.95” N 72o22’27.84” E

Rural Settlement, Top of Linch Panchyat Office



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AAQ11 Sunsar 23o38’47.27” N 72o13’42.98” E

Rural Settlement, Top of Sunsar Panchyat Office

The study area map covering the Ambient Air Quality Monitoring station is depicted in Figure – 3.

Figure – 3.11 Map Showing AAQ monitoring Stations



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AAQ1 BILODRA AAQ2 AJOL

AAQ4 FATEPURA AAQ5 KHERVA

AAQ7 IRANA AAQ8 RUPAL

Fig3.12: Ambient Air monitoring Locations of the Study Area



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3.7.5 Ambient Air Quality Results

Ambient air quality results of PM10, PM2.5, Sulphur Dioxide, Oxides of Nitrogen, Carbon Monoxide,

Methane and Non-Methane Hydrocarbon are given in Annexure-1. Hydrogen Sulphide, Volatile Organic

Compounds and BTX (Benzene, Toluene and Xylene) was not observed in the study Area.

3.7.6. Summary of Ambient Air Quality Result

Summary of ambient air quality results of PM10, PM2.5, Sulphur Dioxide, Oxides of nitrogen, Carbon

monoxide, Methane and Non-Methane Hydrocarbon are summarized in Table 3.7. Volatile Organic

Compounds, BTX (Benzene, Toluene and Xylene), Methane and Non Methane Hydrocarbons were not

reported in study Area.

TABLE-3.7: Summary of Ambient Air Quality Monitoring Results

AAQ Location

PM10 µg/m3 PM2.5 µg/m3 SO2 µg/m3

Min Max Mean 98%le Min Max Mean 98%le Min Max Mean 98%le

AAQ-1 52 75.4 63.9 73.5 20.1 45.1 28.4 42.9 5.9 9.8 6.9 9.3

AAQ-2 49.8 70.5 62.1 70.1 18.6 31.6 24.1 31.1 5.9 11.2 8.1 11.1

AAQ-3 50.1 69.4 61.5 68.9 21.5 29.4 25.1 29.3 5.2 6.8 5.8 6.8

AAQ-4 41.2 62.3 54.5 62.0 21.3 35.4 27.0 33.7 5.2 7.7 6.5 7.7

AAQ-5 52.1 80.4 65.6 76.4 19.8 38.9 27.8 35.7 5.1 7.4 5.8 7.0

AAQ-6 45.9 67.8 58.6 67.0 21.7 29.5 24.5 28.5 5.3 6.8 6.0 6.8

AAQ-7 54.8 70.5 62.2 68.8 21.9 30.8 26.0 30.2 5.1 7.9 6.4 7.7

AAQ-8 51.9 69.3 60.6 67.8 19.8 31.8 24.3 31.1 5.1 6.4 5.8 6.4

AAQ-9 41.3 57.8 50.2 57.5 22.3 31.4 27.1 31.3 5.1 6.9 5.8 6.8

AAQ-10 41.2 60.4 53.9 60.3 22.3 35.4 25.1 32.8 5.3 10.8 6.4 10.1

AAQ-11 52.5 69.9 61.4 69.4 23.1 33.1 27.7 33.0 6.4 14.1 9.9 13.8

NAAQ Standards

100 60 80



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: Source: ABC Techno Labs India Private Limited

The data collected was subjected to statistical analysis like minimum, maximum, average and standard

deviation. The observed ambient air quality data within the study area from the project site is reported

described briefly:

3.7.7 Observations

PM10: The maximum and minimum concentrations for PM10 were recorded as

80.4 g/m3 and 41.2 g/m3 respectively. The maximum concentration was recorded at the Kherva and the

minimum concentration was recorded at Linch. The average concentrations were ranged between

50.2g/m3 – 65.6 g/m3 as shown in figure 3.13.

AAQ Location

NOx µg/m3 CO mg/m3

Min Max Mean 98%le Min Max Mean 98%le

AAQ-1 10.1 24.6 16.7 23.7 0.21 0.39 0.28 0.38

AAQ-2 10.9 19.6 16.5 19.5 0.11 0.19 0.15 0.19

AAQ-3 9.6 13.9 11.5 13.7 0.11 0.19 0.15 0.18

AAQ-4 10.1 12.8 11.3 12.8 0.11 0.19 0.15 0.19

AAQ-5 9.5 19.7 12.7 19.3 0.11 0.23 0.15 0.23

AAQ-6 9.5 14.5 11.5 14.3 0.11 0.19 0.15 0.18

AAQ-7 10.6 17.8 14.8 17.7 0.10 0.19 0.15 0.19

AAQ-8 9.3 19.7 12.7 18.4 0.10 0.21 0.15 0.20

AAQ-9 9.9 14.6 11.9 14.1 0.11 0.19 0.15 0.19

AAQ-10 9.5 12.8 11.4 12.8 0.11 0.19 0.14 0.19

AAQ-11 5.7 7.3 6.3 7.1 0.11 0.19 0.15 0.19

NAAQ Standards

80 2



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Figure 3.13: Variation of Particulate Matter PM10 in the study area

PM2.5: The maximum and minimum concentrations for PM2.5 were recorded as 45.1 g/m3 and 18.6 g/m3

respectively. The maximum concentration was recorded at Shapawada and Bilodra and the minimum

concentration was recorded at Ajol. The average values were observed to be in the range of 24.1g/m3.–

28.4 g/m3 as shown in figure 3.14.

Figure 3.14: Variation of Particulate Matter PM2.5 in the study area

0

20

40

60

80

100C

on

cen

trat

ion

µg/

m3

Sampling Locations

Particulate Matter PM10MinMaxMean98%le

0

10

20

30

40

50

Co

nce

ntr

atio

n µ

g/m

3

Sampling Locations

Particulate Matter 2.5 MinMaxMean98%le



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SO2: The maximum SO2 concentrations were recorded were recorded as 14.1 g/m3 and 5.1 g/m3

respectively. The maximum concentration was recorded at Sunsar and the minimum concentration was

recorded at most of the location as shown in figure 3.15. The average values were observed to be in the

range of 5.8 g/m3- 9.9 g/m3.

Figure 3.15: Variation of Sulphur di oxide (SO2 ) in the study area

NOX: The maximum and minimum NOX concentrations were recorded were recorded as 24.6 g/m3 and

5.7 g/m3 respectively. The maximum concentration was recorded at Chadasana and the minimum

concentration was recorded at Sunsar as shown in figure 3.16 The average values were observed to be

in the range of 6.3 g/m3 to 16.7 g/m3.

Figure 3.16: Variation of Oxides of Nitrogen (NOx) in the study area

0

5

10

15

Co

nce

ntr

atio

n µ

g/m

3

Sampling locations

Sulphur di oxide SO2MinMaxMean98%le

0

5

10

15

20

25

30

AAQ-1 AAQ-2 AAQ-3 AAQ-4 AAQ-5 AAQ-6 AAQ-7 AAQ-8 AAQ-9 AAQ-10 AAQ-11

Co

nce

ntr

atio

n µ

g/m

3

Sampling locations

Oxides of Nitrogen (NOx)MinMaxMean98%le



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CO: The maximum and minimum CO concentrations were recorded as 0.39 mg/m3 and 0.10 mg/m3

respectively. The maximum concentration was recorded at Chadasana and the minimum concentration

was recorded at most of the locations. The average values were observed to be in the range between

0.14mg/m3 to 0.28 mg/m3.

VOCs & BTX: The VOCs & BTX concentrations at all station in the study area were observed to below the

detection limit of 1 g/m3.

Methane HC: The Methane HC concentrations at all station in the study area were observed to be below

the detection limit of 0.1 g/m3.

Non Methane HC: The Non-Methane HC concentrations at all station in the study area were observed to

be below the detection limit of 0.1 g/m3.

The overall concentrations of PM10, PM2.5, SO2, NOX and CO were observed to be well within the standards

prescribed by Central Pollution Control Board (CPCB) for Industrial, Rural, Residential and other area.

3.8 Noise Environment

Noise can be defined as unwanted sound or any sound that is undesirable because it interferes with

speech and hearing, is intense enough to damage hearing or is otherwise annoying. From the noise

source, natural or man-made barriers between the source and the impacted population, weather

conditions which could potentially absorb, reflect, or focus sound (such as wind speed, direction,

temperature inversions), and the scale of industrial activity. The environmental impact of noise can vary

from noise induced hearing loss (NIHL) to annoyance depending on the loudness of noise levels and

tolerance levels of individual.

3.8.1 Methodology for Noise Monitoring

The sound level meter of HTC was used for measuring the Sound Pressure Level (SPL). Sound Pressure

Level (SPL) measurements were recorded at the specified locations continuously for 24 hours. The day

noise levels were recorded between 6 and 10 pm and night noise levels were recorded between 10 pm

and 6 am at all locations.



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3.8.2 Details of Noise Monitoring Locations & Presentation of Results

To quantify noise levels in the study area i.e., 1 km radius from the location, the following criteria was

followed to select sampling stations during field reconnaissance.

Human settlements near the location, which can be affected

Locations of Industrial, residential, commercial, and silence zones in the study area, as per the

CPCB guidelines.

Based on the reconnaissance, the noise quality monitoring stations were identified within the study total

95 locations have been monitored as shown in Figure 3.17; the details of the locations are given in Table

3.8.

Noise Monitoring Stations

Figure – 3.17: Map showing Noise Monitoring Stations



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Table 3.8: Noise level Monitoring of locations

Location Code

Name of the Location

Coordinates Classification of Location

Lday [dB(A)]

Lnight [dB(A)]

Leq [dB(A)]

Standard*

Latitude Longitude Day Night

N1 Near Indrap(1 Km WWN)

23°30'13.54"N

72° 7'34.20"E

Residential Area

48.7 42.0 47.4 55 45

N2 Near Chadsna

23°30'48.08"N

72° 6'18.62"E

Residential Area

53.2 41.1 51.6 55 45

N3 Near Dethali bus stop

23°28'44.55"N

72° 7'9.76"E Residential Area

53.6 42.0 52 55 45

N4 Rantej 23°28'47.23"N

72° 9'36.45"E

Residential Area

53.7 41.4 52.1 55 45

N5 Kakasana 23°37'39.18"N

72°14'3.26"E Residential Area

53.7 41.4 52.1 55 45

N6 Near Dudhsagar Dairy Kakasana

23°38'25.36"N

72°15'33.59"E

Industrial Area

52.9 40.9 51.3 75 70

N7 Near Motap 23°36'52.48"N

72°15'42.85"E

Residential Area

53 41.7 51.4 55 45

N8 Near Mitha Balol Conecting Road

23°32'8.39"N

72°16'28.02"E

Residential Area

54.1 41.3 52.5 55 45

N9 Near SH 216

23°32'8.51"N

72°17'47.45"E

Commercial Area

54.1 41.9 52.5 65 55

N10 Mitha 23°32'42.80"N

72°17'17.90"E

Residential Area

53.3 39.8 51.6 55 45

N11 Near Gujarat State Highway 218

23°37'44.63"N

72°33'41.18"E

Residential Area

52.8 40.5 51.2 55 45

N12 Near Visnagar Mansa Road

23°36'1.70"N

72°35'44.35"E

Residential Area

52.8 41.4 51.2 55 45

N13 Near Dhandusan

23°30'0.48"N

72°33'24.63"E

Residential Area

53.1 41.7 51.5 55 45

N14 Bilodra 23°31'40.02"N

72°38'58.92"E

Residential Area

53.5 41.6 51.9 55 45



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N15 Near Harnahoda

23°29'55.17"N

72°35'56.09"E

Residential Area

53.2 41 51.6 55 45

N16 Near Motipura

23°32'10.62"N

72°36'20.41"E

Residential Area

54.2 41.9 52.6 55 45

N17 Kherva 23°32'43.11"N

72°26'25.06"E

Residential Area

55.2 40.3 53.5 55 45

N18 Near Padharia

23°31'6.46"N

72°31'34.70"E

Residential Area

53.6 41.3 52 55 45

N19 Langhanaj 23°27'2.13"N

72°29'38.98"E

Commercial Area

53.8 41 52.2 65 55

N20 Gozaria 23°28'29.66"N

72°33'47.01"E

Commercial Area

54.4 42 52.8 65 55

N21 Saldi 23°25'27.58"N

72°31'38.51"E

Residential Area

54.0 40.4 52.3 55 45

N22 Mehsana 23°35'8.55"N

72°22'11.44"E

Commercial Area

53.2 41.7 51.6 65 55

N23 Jotana 23°28'13.68"N

72°17'31.92"E

Residential Area

52.9 38.8 51.2 55 45

N24 Memadpur 23°25'23.77"N


54.5 39 52.8 55 45

N25 Jakasana 23°26'18.89"N

72°18'48.70"E

Residential Area

54.2 38.4 52.5 55 45

N26 Ambassan 23°28'44.78"N

72°20'54.56"E

Residential Area

51.5 38.9 49.9 55 45

N27 Linch 23°29'53.78"N

72°22'38.08"E

Residential Area

53.1 42 51.5 55 45

N28 Divanpura 23°26'39.06"N

72°21'13.11"E

Residential Area

53.7 41.9 52.1 55 45

N29 Suraj 23°23'30.41"N

72°18'18.20"E

Commercial Area

53.9 41.8 52.3 65 55

N30 Nani Kadi Part

23°16'9.03"N

72°19'22.20"E

Residential Area

54.4 41 52.7 55 45

N31 Kadi Railway Stn

23°17'32.31"N

72°19'30.99"E

Residential Area

53.4 40.1 51.7 55 45

N32 Irana 23°18'46.63"N


52 40.5 50.4 55 45

N33 Dhinoj 23°39'43.19"N

72°16'44.41"E

Residential Area

53.8 41.7 52.2 55 45

N34 Lanva 23°41'2.23"N

72°14'40.26"E

Residential Area

54.8 42 53.2 55 45

N35 Rampura Bus Stop

23°33'50.87"N

72°25'29.68"E

Residential Area

53.2 41.8 51.6 55 45

N36 Ucharapi Rd

23°36'0.71"N

72°24'29.44"E

Commercial Area

52.3 41.8 50.7 65 55

N37 Mansa 23°26'0.66"N

72°39'23.37"E

Commercial Area

53 42 51.4 65 55



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N38 Ridrol 23°27'34.75"N

72°40'32.09"E

Commercial Area

52.9 41.6 51.3 65 55

N39 Ganeshpura

23°24'16.62"N

72°23'25.98"E

Residential Area

53.9 41.8 52.3 55 45

N40 Mathasur 23°23'4.33"N

72°22'15.74"E

Residential Area

54.9 40.9 53.2 55 45

N41 Kadi-nandsan Road

23°21'48.90"N

72°23'11.72"E

Residential Area

53.3 41.5 51.7 55 45

N42 Anandpura road

23°22'59.20"N

72°25'41.31"E

Residential Area

53.1 41.6 51.5 55 45

N43 Nandasan 23°22'16.59"N

72°24'29.36"E

Commercial Area

53.5 41.9 51.9 65 55

N44 Chanasma 23°43'7.10"N

72° 7'12.23"E

Commercial Area

53.6 41.4 52 65 55

N45 Balol 23°30'56.80"N

72°14'54.30"E

Residential Area

53.9 41.4 52.3 55 45

N46 Kasalpura 23°29'0.81"N

72°17'41.98"E

Residential Area

52.8 41.3 51.2 55 45

N47 Santhal 23°29'0.03"N

72°15'19.94"E

Commercial Area

53.9 40.5 52.2 65 55

N48 Hevuba 23°33'0.12"N

72°24'29.99"E

Residential Area

53.6 41.2 52 55 45

N49 Punasan 23°32'8.89"N

72°24'37.15"E

Residential Area

53.7 41.8 52.1 55 45

N50 Mevad 23°31'45.38"N

72°23'20.61"E

Residential Area

52.9 41.4 51.3 55 45

N51 Heduva Rajgar

23°33'53.62"N


52.5 41.3 50.9 55 45

N52 Sukhpurda 23°32'36.30"N

72°22'23.06"E

Residential Area

53.2 41.6 51.6 55 45

N53 Katpur 23°47'55.12"N

72° 5'38.75"E

Residential Area

53.3 41.7 51.7 55 45

N54 Near Katosan

23°27'3.49"N


52.8 41.5 51.2 55 45

N55 Katosan 23°27'40.80"N


54 41.3 52.4 55 45

N56 Tejpura 23°27'57.94"N

72°12'30.09"E

Residential Area

53.8 41.1 52.2 55 45

N57 Amarpura 23°25'50.86"N

72°13'23.45"E

Residential Area

53.2 41.6 51.6 55 45

N58 Virsoda 23°26'25.98"N

72°11'40.70"E

Residential Area

53.4 41.4 51.8 55 45

N59 Moti Rantai 23°24'40.69"N

72°11'48.60"E

Residential Area

53.8 41.7 52.2 55 45



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N60 Madrisana 23°23'21.55"N

72°12'47.59"E

Residential Area

52 41.5 50.4 55 45

N61 Rampura

23°27'52.98"N

72°10'35.95"E

Residential Area

54.2 41.6 52.6 55 45

N62 Indrap 23°30'5.07"N

72° 8'8.51"E Residential Area

54.1 40.8 52.4 55 45

N63 Chadasna 23°30'35.69"N

72° 6'43.16"E

Commercial Area

51 41.5 49.5 65 55

N64 Dholasan 23°24'21.39"N

72°20'14.56"E

Residential Area

52.3 41.1 50.7 55 45

N65 Ganpatpura

23°23'45.74"N

72°19'27.92"E

Commercial Area

54.5 41.3 52.8 65 55

N66 Kadi GIDC 23°17'26.31"N

23°17'26.31"N

Commercial Area

53.9 40.1 52.2 65 55

N67 Kadi 23°17'52.33"N

72°19'51.61"E

Commercial Area

54 40.7 52.3 65 55

N68 Kasba 23°18'11.78"N

72°19'49.36"E

Residential Area

52.8 41.3 51.2 55 45

N69 Chalasan 23°24'16.25"N

72°18'10.76"E

Commercial Area

54.3 39 52.6 65 55

N70 Khara 23°31'41.28"N

72°17'52.08"E

Residential Area

53.4 38.5 51.7 55 45

N71 Devinapura 23°33'32.40"N

72°17'26.82"E

Residential Area

53.3 38.7 51.6 55 45

N72 Mahesana GIDC

23°35'25.33"N

72°22'20.31"E

Commercial Area

52.2 41.2 50.6 65 55

N73 Vidhyanagar

23°34'43.78"N

72°21'50.18"E

Residential Area

52.2 41 41 55 45

N74 Heduva 23°34'2.87"N


52.9 41 51.3 55 45

N75 RTO 23°34'22.84"N

72°21'55.75"E

Commercial Area

53.3 41.1 51.7 65 55

N76 Palwasana Part

23°33'33.61"N

72°22'20.24"E

Residential Area

52.9 41.3 51.3 55 45

N77 Laghnaj 23°26'52.05"N

72°29'54.66"E

Commercial Area

52.6 39.8 51 65 55

N78 ONGC Nagar

23°36'7.61"N

72°22'34.75"E

Residential Area

54 41.6 52.4 55 45

N79 Suraj 23°23'25.39"N

72°18'40.00"E

Residential Area

52.7 39.8 51 55 45

N80 Mokasan 23°22'3.51"N

72°19'25.22"E

Residential Area

51.4 40.2 49.8 55 45

N81 Jagudan 23°30'49.26"N

72°24'57.72"E

Residential Area

54.1 40.4 52.4 55 45

N82 Kochava 23°30'15.54"N


52.8 40.1 51.2 55 45



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Standard as per Environmental Protection Act 1986, the principle rules published for Ambient Noise

Level Standard (Area Category: Industrial/Residential/Commercial Area

N83 Baliasan 23°27'20.50"N

72°23'40.94"E

Residential Area

54 39 52.3 55 45

N84 Palwasana Part

23°33'20.60"N


55.7 38.5 54 55 45

N85 Ranipura 23°27'34.55"N

72°18'59.79"E

Residential Area

54.3 38.9 52.6 55 45

N86 Lijpura Jethaji

23°26'32.20"N

72°17'25.93"E

Residential Area

53.7 38.7 52 55 45

N87 Memadpur 23°25'22.49"N

72°18'56.69"E

Residential Area

54.1 38.9 52.4 55 45

N88 Ganeshpura

23°38'6.04"N


53.8 39 52.1 55 45

N89 Vadasma 23°24'36.37"N

72°29'17.78"E

Commercial Area

53.1 41.1 51.5 65 55

N90 Mandali 23°25'45.11"N

72°23'56.84"E

Residential Area

52 41.7 50.4 55 45

N91 Ganget 23°43'35.70"N

72°10'29.33"E

Residential Area

53.1 41.1 51.5 55 45

N92 Keshani 23°42'37.25"N

72°10'40.59"E

Residential Area

54.1 41.4 52.5 55 45

N93 Jasalpur 23°42'39.48"N

72° 7'12.23"E

Residential Area

54.1 41.5 52.5 55 45

N94 Suncity Society

23°36'9.29"N

72°22'15.36"E

Residential Area

53.8 41.8 52.2 55 45

N95 Near Gamanpura

23°32'58.62"N

72°16'11.13"E

Residential Area

53.1 40.4 51.5 55 45



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3.8.3 Observations

Day time Noise Levels

Noise levels during day time were found to be in the average range of 47.9 to 55.7 dB (A). The maximum

noise level was observed as 55.7 dB (A) at Palwasana Part (N-69) and a minimum of 48.7dB (A) was

observed at Near Near Indrap (N2).

Night time Noise Levels

Noise levels observed to fall in the range 38.4 to 42 dB (A) during the night time. A maximum of 42 dB

(A) was observed at Mansa (N-37), Lanva (N-34), Linch (N-27), Indrap (N-1) and a minimum of 38.4 dB

(A) was observed at Jakasana (N-75).

In residential zone the noise levels were found to meet the Ambient Air Quality Standards in respect of

Noise (henceforth Noise Standards 2000) as given in Noise Rules 2000, during day and night time. Within

the proposed location, the noise levels were within the OSHA damage risk criteria for hearing. The area

which is located at a lower elevation and has dense vegetation, which would prevent noise propagation

to nearby villages. Many of the activities such as construction, bus/auto station and traffic causing noise

are temporary in nature.

Figure 3.18: Noise Monitoring Locations

Noise 1- Near Chadsna Noise 2- Near Visnagar Mansa Road



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Noise 3-Mehsana Noise 4-Jotana

Noise 5- Balol Noise 6-Khara

Noise 7- Laghnaj Noise 8- Suraj



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3.9 Water Environment

3.9.1 Reconnaissance

A reconnaissance survey was undertaken to identify the sampling locations to establish baseline status

of water quality in the study area. Based on the reconnaissance survey, the type of water bodies and

their relative importance with the project site and environmental issues within study area; surface and

ground water sampling locations were identified and water samples were collected in summer season.

3.9.2 Water Quality Monitoring

Selected water quality parameters of the Ground water resources within the project area have been studied

for assessing the water environment. Water samples were examined for Physico-chemical, Heavy metals

and Bacteriological parameters in order to assess the effect of industrial, vehicular and other activities on

ground or surface water.

3.9.3. Sampling and Analysis Techniques

Samples for chemical analysis were collected in polyethylene carboys. Samples collected for metal content

were acidified with 1 ml HNO3. Samples for bacteriological analysis were collected in sterilized bottles. The

samples were analyzed as per the procedures specified in IS methods and 'Standard Methods for the

Examination of Water and Wastewater' published by American Public Health Association (APHA).

3.9.4 Details of Water Sampling Locations

Seven (7) Ground Water and Fourteen (14) Surface water samples were collected to establish baseline

water quality of the study area. The Ground water sampling locations are listed in the Table-3.9 & locations

for Surface water samples are listed in the Table 3.10

TABLE 3.9– GROUND WATER SAMPLING LOCATIONS



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Location Code Name of the Location

Coordinates Latitude Longitude

GW1 Fatepura 23°25'56.08"N 72°38'12.90"E

GW2 Sunsar 23°38'49.61"N 72°13'38.02"E

GW3 Suraj 23°23'41.02"N 72°18'49.36"E

GW4 Kherva 23°32'36.80"N 72°26'30.28"E

GW5 Rupal 23°41'3.68"N 72°20'35.16"E

GW6 Lagnaj 23°26'50.30"N 72°29'50.45"E

GW7 Linch 23°29'43.82"N 72°22'17.93"E

TABLE 3.10 – SURFACE WATER SAMPLING LOCATIONS

Location Code Name of the Location

Coordinates Latitude Longitude

SW1 Lodra 23°27'21.46"N 72°43'12.14"E

SW2 Ridrol 23°27'25.93"N 72°40'48.15"E

SW3 Kherva 23°32'47.80"N 72°26'25.50"E

SW4 Langhnaj

23°26'41.94"N 72°29'53.46"E

SW5 Rupal 23°41'5.12"N 72 20'34.41"E

SW6 Linch 23°29'34.72"N 72°22'26.79"E

SW7 Ubkal 23°34'11.49"N 72°37'34.25"E

SW8 Kadi 23°16'6.83"N 72°19'23.57"E

SW9 Rupal (Narmada canal)

23°41'15.69"N 72°20'30.91"E

SW10 Delwad

23°23'12.24"N 72°43'19.44"E



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SW11 Khari

23°34'23.75"N 72°21'2.86"E

SW12 Udhalpur

23°33'31.20"N 72°29'12.21"E

SW13 Motidau

23°40'59.42"N 72°24'8.25"E

SW14 Mansa

23°25'48.28"N 72°39'22.77"E

The study area map covering the Water sampling Locations is enclosed as Figure – 3.19,

Figure – 3.19: Map Showing Ground Water & Surface Water monitoring Stations



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3.9.5 Presentation of Results

The sampling results for the ground water and surface water samples were tabulated in Table – 3.11 &

Table 3.12 (a) & (b) respectively. The analysed results are compared with the Acceptable Drinking water

standard as per IS: 10500:2012 for both Ground water and Surface water.



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Table 3.11 (a): Results of Ground Water sampling locations

S.No Parameters Unit Procedure GW1 GW2 GW3 GW4 Acceptable Limit as per IS 10500:2012

1 Colour Hazen APHA 22nd Edition (Reaff:2012) Nil 2 Nil 1 5

2 Temperature °C APHA 22nd Edition (Reaff:2012) 26.2 25.8 25.8 26.1 Not Specified

3 pH at 25°C - IS : 3025 Part 11- 1983 (Reaff:2012)

7.80 7.57 8.01 7.71 6.5-8.5

4 Electrical Conductivity

μS/cm IS : 3025 Part 14- 1984 (Reaff: 2012)

863 2680 1080 1060 Not Specified

5 Turbidity NTU IS : 3025 Part 10-1984 (Reaff: 2012)

0.5 1.2 BDL(<0.5) 0.8 1

6 Total Dissolved Solids

mg/l IS : 3025 Part 16-1984 (Reaff: 2012)

480 1512 610 604 500

7 Total Hardness as CaCO3

mg/l IS : 3025 Part 21-2009 (Reaff: 2014)

264 560 228 248 200

8 Total Alkalinity as CaCO3

mg/l IS : 3025 Part 23- 1986 (Reaff:2012)

260 330 250 268 200

9 Chloride as Cl mg/l IS : 3025 Part 32-1988 (Reaff: 2014)

105 645 220 195 250

10 Sulphate as SO4

mg/l APHA 22nd Edition -4500- SO42- E

14 128 9 11 200

11 Fluoride as F mg/l APHA 22nd Edition-4500-F B&D 0.58 0.99 1.22 0.56 1

12 Nitrate as NO3 mg/l APHA 22nd Edition -4500- NO3- B

31 7.4 1.5 23 45

13 Ammonical Nitrogen

mg/l APHA 22nd Edition -4500- NH3 B&C

0.34 0.18 BDL(<0.05) 0.34 Not Specified



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14 Total Nitrogen as N

mg/l APHA 22nd Edition -4500- N&C,NO3 E

7.36 2.08 1 0.65 Not Specified

15 Total Phosphorous

mg/l IS : 3025 Part 31-1988 (Reaff:2014)

0.21 0.15 0.25 0.13 Not Specified

16 Sodium as Na mg/l IS : 3025 Part 45-1993 (Reaff:2014)

75 320 136 122 Not Specified

17 Potassium as K mg/l IS : 3025 Part 45-1993 (Reaff:2014)

3 10 6 5 Not Specified

18 Calcium as Ca mg/l IS : 3025 Part 40-1991 (Reaff:2014)

53 104 46 45 75

19 Magnesium as Mg

mg/l APHA 22nd Edition-3500 Mg-B 32 73 27 33 30

20 Iron as Fe mg/l IS : 3025 Part 53-2003 BDL(< 0.05)

0.3 BDL(< 0.05)

0.165 1

21 Manganese as Mn

mg/l APHA 22nd EDN -3500-Mn D BDL(< 0.02)

BDL(< 0.02)

BDL(< 0.02)

BDL(< 0.02) 0.10

22 Dissolved Oxygen as O2

mg/l IS:3025:Part-38:1989 (Reaff:2003) 3.9 4.1 4.3 3.9 Not Specified

23 Chemical Oxygen Demand

mg/l IS:3025:Part-58:2006 (Reaff:2012)

BDL(<4) BDL(<4) BDL(<4) 4.4 Not Specified

24

Bio-Chemical Oxygen Demand @ 27°C for 3 days

mg/l IS:3025:Part-44:1993 (Reaff:2014)

<2 <2 <2 <2 Not Specified

25 Copper as Cu mg/l APHA 22nd Edition -3111 B BDL(< 0.03)

BDL(< 0.03)

BDL(< 0.03)

BDL(< 0.03)

0.05



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26 Mercury as Hg mg/l APHA 22nd Edition -3112 B BDL(< 0.001)

BDL(< 0.001)

BDL(< 0.001)

BDL(< 0.001)

0.001

27 Cadmium as Cd

mg/l APHA 22nd Edition -3111 B BDL(< 0.003)

BDL(< 0.003)

BDL(< 0.003)

BDL(< 0.003)

0.003

28 Total Arsenic as As


BDL(< 0.01)

BDL(< 0.01)

BDL(< 0.01)

0.01

29 Cyanide as CN mg/l APHA 22nd Edition -4500 CN BDL(< 0.05)

BDL(< 0.05)

BDL(< 0.05)

BDL(< 0.05)

0.05

30 Lead as Pd mg/l APHA 22nd Edition -3111 B BDL(< 0.01)

BDL(< 0.01)

BDL(< 0.01)

BDL(< 0.01)

0.01

31 Zinc as Zn mg/l APHA 22nd Edition -3111 B 0.019 0.24 0.156 0.278 5

32 Hexavalent Chromium as Cr6+

mg/l APHA 22nd Edition -3500 Cr B BDL(< 0.01)

BDL(< 0.01)

BDL(< 0.01)

BDL(< 0.01)

Not Specified

33 Total Chromium as Cr


BDL(< 0.02)

BDL(< 0.02)

BDL(< 0.02) 0.05

34 Nickel as Ni mg/l APHA 22nd Edition -3111 B BDL(< 0.02)

BDL(< 0.02)

BDL(< 0.02)

BDL(< 0.02)

0.02

35 Sodium Absorption Ratio

_ Calculation 2.01 5.88 3.93 3.37 Not Specified

36 Salinity %0 APHA 22nd Edition -2520 B 0.5 1.5 0.6 0.6 Not Specified

37 Calcium Hardness as CaCO3

mg/l IS:3025:Part-40:(Reaff:2014) 132 260 116 112 Not Specified

38 Magnesium Hardness as CaCO3

mg/l APHA 22nd Edition -3500 Mg B 132 300 112 136 Not Specified



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39 Molybdenum as Mo

mg/l APHA 22nd Edition -3111 D BDL(< 0.05)

BDL(< 0.05)

BDL(< 0.05)

BDL(< 0.05)

0.07

40 Total Coliform MPN/ 100ml

IS :1622 (1981) 6 <2 <2 26 Absent

41 Faecal coliform MPN/ 100ml

IS:1622 (1981) <2 <2 <2 <2 Absent

42. Total Suspended Solids

mg/l IS:3025 Part 17 <1 <1 <1 <1 Not Specified

Table 3.11 (b): Results of Ground Water sampling locations

S.No Parameters Unit Procedure GW5 GW6 GW7 Acceptable Limit as per IS 10500:2012

1 Colour Hazen APHA 22nd Edition (Reaff:2012) 1 2 Nil 5

2 Temperature °C APHA 22nd Edition (Reaff:2012) 26.1 25.2 25.8 Not Specified

3 pH at 25°C - IS : 3025 Part 11- 1983 (Reaff:2012) 7.68 7.65 7.87 6.5-8.5

4 Electrical Conductivity

μS/cm IS : 3025 Part 14- 1984 (Reaff: 2012)

2310 1350 1020 Not Specified

5 Turbidity NTU IS : 3025 Part 10-1984 (Reaff: 2012) 1.3 1.5 BDL(<0.5) 1

6 Total Dissolved Solids

mg/l IS : 3025 Part 16-1984 (Reaff: 2012) 1350 770 564 500

7 Total Hardness as CaCO3

mg/l IS : 3025 Part 21-2009 (Reaff: 2014) 396 292 228 200

8 Total Alkalinity as CaCO3

mg/l IS : 3025 Part 23- 1986 (Reaff:2012) 390 288 260 200

9 Chloride as Cl mg/l IS : 3025 Part 32-1988 (Reaff: 2014) 540 260 180 250



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10 Sulphate as SO4

mg/l APHA 22nd Edition -4500- SO42- E 42 12 8 200

11 Fluoride as F mg/l APHA 22nd Edition-4500-F B&D 1.2 0.65 0.23 1

12 Nitrate as NO3 mg/l APHA 22nd Edition -4500- NO3- B 28 17 41 45

13 Ammonical Nitrogen

mg/l APHA 22nd Edition -4500- NH3 B&C 0.43 0.41 0.12 Not Specified

14 Total Nitrogen as N

mg/l APHA 22nd Edition -4500- N&C,NO3 E

6.22 3.74 9.74 Not Specified

15 Total Phosphorous

mg/l IS : 3025 Part 31-1988 (Reaff:2014) 0.13 0.42 0.09 Not Specified

16 Sodium as Na mg/l IS : 3025 Part 45-1993 (Reaff:2014) 342 203 105 Not Specified

17 Potassium as K mg/l IS : 3025 Part 45-1993 (Reaff:2014) 4 4 3 Not Specified

18 Calcium as Ca mg/l IS : 3025 Part 40-1991 (Reaff:2014) 58 61 43 75

19 Magnesium as Mg

mg/l APHA 22nd Edition-3500 Mg-B 61 34 48 30

20 Iron as Fe mg/l IS : 3025 Part 53-2003 0.195 0.216 BDL(<0.05) 1

21 Manganese as Mn

mg/l APHA 22nd EDN -3500-Mn D BDL(< 0.02)

BDL(< 0.02)

BDL(< 0.02) 0.10

22 Dissolved Oxygen as O2

mg/l IS:3025:Part-38:1989 (Reaff:2003) 3.4 4.1 3.7 Not Specified

23 Chemical Oxygen Demand

mg/l IS:3025:Part-58:2006 (Reaff:2012) BDL(< 4)

BDL(< 4) 15 Not Specified

24

Bio-Chemical Oxygen Demand @ 27°C for 3 days

mg/l IS:3025:Part-44:1993 (Reaff:2014) <2 <2 <2 Not Specified

25 Copper as Cu mg/l APHA 22nd Edition -3111 B BDL(< 0.03)

BDL(< 0.03)

BDL(< 0.03)

0.05



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94

26 Mercury as Hg mg/l APHA 22nd Edition -3112 B BDL(< 0.001)

BDL(< 0.001)

BDL(< 0.001)

0.001

27 Cadmium as Cd


BDL(< 0.003)

BDL(< 0.003)

0.003

28 Total Arsenic as As


BDL(< 0.01)

BDL(< 0.01)

0.01

29 Cyanide as CN mg/l APHA 22nd Edition -4500 CN BDL(< 0.05)

BDL(< 0.05)

BDL(< 0.05)

0.05

30 Lead as Pd mg/l APHA 22nd Edition -3111 B BDL(< 0.01)

BDL(< 0.01)

BDL(< 0.01)

0.01

31 Zinc as Zn mg/l APHA 22nd Edition -3111 B 0.06 0.272 0.316 5

32 Hexavalent Chromium as Cr6+

mg/l APHA 22nd Edition -3500 Cr B BDL(< 0.01)

BDL(< 0.01)

BDL(< 0.01)

Not Specified

33 Total Chromium as Cr


BDL(< 0.02)

BDL(< 0.02) 0.05

34 Nickel as Ni mg/l APHA 22nd Edition -3111 B BDL(< 0.02)

BDL(< 0.02)

BDL(< 0.02)

0.02

35 Sodium Absorption Ratio

_ Calculation 7.47 5.16 2.61 Not Specified

36 Salinity %0 APHA 22nd Edition -2520 B 1.4 0.8 0.6 Not Specified

37 Calcium Hardness as CaCO3

mg/l IS:3025:Part-40:(Reaff:2014) 144 152 108 Not Specified

38 Magnesium Hardness as CaCO3

mg/l APHA 22nd Edition -3500 Mg B 252 140 120 Not Specified



Rev. No. 02


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95

39 Molybdenum as Mo

mg/l APHA 22nd Edition -3111 D BDL(< 0.05)

BDL(< 0.05)

BDL(< 0.05)

0.07

40 Total Coliform MPN/ 100ml

IS :1622 (1981) <2 4 23 Absent

41 Faecal coliform MPN/ 100ml

IS:1622 (1981) <2 <2 <2 Absent

42. Total Suspended Solids

mg/l IS:3025 Part 17 <1 1 <1 Not Specified

TABLE –3.12 (a): SURFACE WATER ANALYSIS RESULTS

S.N

o Parameters Unit Procedure

SW1 SW2 SW3 SW4 SW5

Acceptable Limit as

per IS 10500:2012

1 Colour Hazen APHA 22nd Edition (Reaff:2012) 10 55 15 3 8 5

2 Temperature °C APHA 22nd Edition (Reaff:2012) 26 25.3 26.5 26.3 25.6 Not Specified

3 pH at 25°C - IS : 3025 Part 11- 1983 (Reaff:2012) 7.14 7.3 7.47 7.3 7.16 6.5-8.5

4 Electrical Conductivity μS/cm IS : 3025 Part 14- 1984 (Reaff: 2012) 270 1532 1070 520 1630 Not Specified

5 Turbidity NTU IS : 3025 Part 10-1984 (Reaff: 2012) 6.6 14.1 12.8 2.2 7 1

6 Total Dissolved Solids mg/l IS : 3025 Part 16-1984 (Reaff: 2012) 325 858 612 290 930 500



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96

7 Total Hardness as

CaCO3 mg/l IS : 3025 Part 21-2009 (Reaff: 2014)

132 330 180 160 240

200

8 Total Alkalinity as CaCO3 mg/l IS : 3025 Part 23- 1986 (Reaff:2012) 160 252 260 160 190 200

9 Chloride as Cl mg/l IS : 3025 Part 32-1988 (Reaff: 2014) 75 303 190 67 381 250

10 Sulphate as SO4 mg/l APHA 22nd Edition -4500- SO42- E 8 76 21 8 58 200

11 Fluoride as F mg/l APHA 22nd Edition-4500-F B&D 0.49 0.56 0.49 0.19 0.55 1

12 Nitrate as NO3 mg/l APHA 22nd Edition -4500- NO3- B 21 39 16 11 19 45

13 Ammonical Nitrogen mg/l APHA 22nd Edition -4500- NH3 B&C 2.63 0.53 2.23 1.36 3.11 Not Specified

14 Total Nitrogen as N mg/l APHA 22nd Edition -4500- N&C,NO3

E

8.36 21.8 5.14 4.13 9.63

Not Specified

15 Total Phosphorous mg/l IS : 3025 Part 31-1988 (Reaff:2014) 0.51 0.13 0.64 0.11 0.5 Not Specified

16 Sodium as Na mg/l IS : 3025 Part 45-1993 (Reaff:2014) 60 169 142 45 216 Not Specified

17 Potassium as K mg/l IS : 3025 Part 45-1993 (Reaff:2014) 13 20 17 5 25 Not Specified

18 Calcium as Ca mg/l IS : 3025 Part 40-1991 (Reaff:2014) 24 56 32 30 40 75

19 Magnesium as Mg mg/l APHA 22nd Edition-3500 Mg-B 17 46 24 20 34 30

20 Iron as Fe mg/l IS : 3025 Part 53-2003 1.96 5.46 1.21 2.89 3.88 1

21 Manganese as Mn mg/l APHA 22nd EDN -3500-Mn D

BDL(< 0.02)

0.07

BDL(

<

0.02)

0.07

0.2 0.09

0.10



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97

22 Dissolved Oxygen as O2 mg/l IS:3025:Part-38:1989 (Reaff:2003) 4.8 4.8 5.5 6.6 5.1 Not Specified

23 Chemical Oxygen

Demand mg/l IS:3025:Part-58:2006 (Reaff:2012)

28 40 54 17 33 Not Specified

24

Bio-Chemical Oxygen

Demand @ 27°C for 3

days

mg/l IS:3025:Part-44:1993 (Reaff:2014)

4.9

6.2 8.2 2.1 4.4 Not Specified

25 Copper as Cu mg/l APHA 22nd Edition -3111 B BDL(< 0.03) BDL(<

0.03)

BDL(<

0.03)

BDL(<

0.03) 0.12 0.05

26 Mercury as Hg mg/l APHA 22nd Edition -3112 B BDL(< 0.001) BDL(<

0.001)

BDL(<

0.001)

BDL(<

0.001) BDL(< 0.001) 0.001

27 Cadmium as Cd mg/l APHA 22nd Edition -3111 B BDL(< 0.003) BDL(<

0.003)

BDL(<

0.003)

BDL(<

0.003) BDL(< 0.003) 0.003

28 Total Arsenic as As mg/l APHA 22nd Edition -3114 B BDL(< 0.01) BDL(<

0.01)

BDL(<

0.01)

BDL(<

0.01) BDL(< 0.01) 0.01

29 Cyanide as CN mg/l APHA 22nd Edition -4500 CN BDL(< 0.05) BDL(<

0.05)

BDL(<

0.05)

BDL(<

0.05) BDL(< 0.05) 0.05

30 Lead as Pd mg/l APHA 22nd Edition -3111 B 0.013 BDL(<

0.01)

BDL(<

0.01)

BDL(<

0.01) BDL(< 0.01) 0.01

31 Zinc as Zn mg/l APHA 22nd Edition -3111 B 0.396 0.71 0.841 0.214 0.166 5

32 Hexavalent Chromium as

Cr6+ mg/l APHA 22nd Edition -3500 Cr B

BDL(< 0.01) BDL(<

0.01)

BDL(<

0.01)

BDL(<

0.01) BDL(< 0.01) Not Specified

33 Total Chromium as Cr mg/l APHA 22nd Edition -3111 B BDL(< 0.02) BDL(<

0.02)

BDL(<

0.02)

BDL(<

0.02)

BDL(< 0.02) 0.05



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98

34 Nickel as Ni mg/l APHA 22nd Edition -3111 B BDL(< 0.02) BDL(<

0.02)

BDL(<

0.02)

BDL(<

0.02) BDL(< 0.02) 0.02

35 Sodium Absorption Ratio _ Calculation 2.29 4.05 4.62 1.56 6.06 Not Specified

36 Salinity %0 APHA 22nd Edition -2520 B 0.4 0.9 1.1 0.3 1.6 Not Specified

37 Calcium Hardness as

CaCO3 mg/l IS:3025:Part-40:(Reaff:2014)

60 140 80 76 100 Not Specified

38 Magnesium Hardness as

CaCO3 mg/l APHA 22nd Edition -3500 Mg B

72 190 100 84 140 Not Specified

39 Molybdenum as Mo mg/l APHA 22nd Edition -3111 D

BDL(< 0.05) BDL(<

0.05)

BDL(

<

0.05)

BDL(

<

0.05)

BDL(< 0.05) 0.07

40 Total Coliform MPN/

100ml IS :1622 (1981)

170 17 350 90 110 Absent

41 Faecal coliform MPN/

100ml IS:1622 (1981)

33 4 17 11 14 Absent



Rev. No. 02


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99

TABLE – 3.12 (b): SURFACE WATER ANALYSIS RESULTS

S.No Parameters Unit Procedure SW6 SW7 SW8

SW9 SW10

Acceptable

Limit as per

IS 10500:2012

1 Colour Haze

n APHA 22nd Edition (Reaff:2012) 25 6 6

3 2 5

2 Temperature °C APHA 22nd Edition (Reaff:2012) 26.8 25.7 26.6 25.7 25.4 Not Specified

3 pH at 25°C - IS : 3025 Part 11- 1983 (Reaff:2012) 7.42 7.31 7.39 6.69 7.38 6.5-8.5

4 Electrical Conductivity μS/c

m

IS : 3025 Part 14- 1984 (Reaff:

2012) 1590 990 941

394 291

Not Specified

5 Turbidity NTU IS : 3025 Part 10-1984 (Reaff: 2012) 10.8 2.2 3.3 2 1.5 1

6 Total Dissolved Solids mg/l IS : 3025 Part 16-1984 (Reaff: 2012) 890 562 522 211 161 500

7 Total Hardness as CaCO3 mg/l IS : 3025 Part 21-2009 (Reaff: 2014) 220 120 210 124 110 200

8 Total Alkalinity as CaCO3 mg/l IS : 3025 Part 23- 1986 (Reaff:2012) 240 240 270 121 100 200

9 Chloride as Cl mg/l IS : 3025 Part 32-1988 (Reaff: 2014) 317 116 135 44 27 250

10 Sulphate as SO4 mg/l APHA 22nd Edition -4500- SO42- E 96 65 32 16 11 200

11 Fluoride as F mg/l APHA 22nd Edition-4500-F B&D 0.64 0.81 0.74 0.36 0.63 1

12 Nitrate as NO3 mg/l APHA 22nd Edition -4500- NO3- B 5 1.7 BDL(<1) BDL(<1) BDL(<

1)

45



Rev. No. 02


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100

13 Ammonical Nitrogen mg/l APHA 22nd Edition -4500- NH3

B&C 1.44 1.36 0.14

0.1 0.05

Not Specified

14 Total Nitrogen as N mg/l APHA 22nd Edition -4500-

N&C,NO3 E 2.63 2.05 2

1.11 1

Not Specified

15 Total Phosphorous mg/l IS : 3025 Part 31-1988 (Reaff:2014) 0.46 0.31 0.2 0.03 0.32 Not Specified

16 Sodium as Na mg/l IS : 3025 Part 45-1993 (Reaff:2014) 220 140 96 29 15 Not Specified

17 Potassium as K mg/l IS : 3025 Part 45-1993 (Reaff:2014) 27 33 11 9 3 Not Specified

18 Calcium as Ca mg/l IS : 3025 Part 40-1991 (Reaff:2014) 20 16 44 27 24 75

19 Magnesium as Mg mg/l APHA 22nd Edition-3500 Mg-B 41 19 40 13 13 30

20 Iron as Fe mg/l IS : 3025 Part 53-2003 1.41 0.31 0.41 0.26 0.25 1

21 Manganese as Mn mg/l APHA 22nd EDN -3500-Mn D BDL<

0.02 BDL< 0.02

BDL(<

0.02)

BDL(<

0.02)

BDL(<

0.02) 0.10

22 Dissolved Oxygen as O2 mg/l IS:3025:Part-38:1989 (Reaff:2003) 4.8 5.9 6.5 6.7 6.5 Not Specified

23 Chemical Oxygen

Demand mg/l IS:3025:Part-58:2006 (Reaff:2012) 60 16 12

18 16 Not Specified

24

Bio-Chemical Oxygen

Demand @ 27°C for 3

days

mg/l IS:3025:Part-44:1993 (Reaff:2014) 10.4 2 2

2.4

2.2 Not Specified

25 Copper as Cu mg/l APHA 22nd Edition -3111 B 0.11 BDL(<0.03 BDL(<0.0

3)

BDL(<0.

03)

BDL(<

0.03 0.05



Rev. No. 02


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101

26 Mercury as Hg mg/l APHA 22nd Edition -3112 B BDL(<

0.001)

BDL(<0.001

)

BDL(<0.0

01)

BDL(<0.

001)

BDL(<

0.001) 0.001

27 Cadmium as Cd mg/l APHA 22nd Edition -3111 B BDL(<

0.003)

BDL(<0.003

)

BDL(<0.0

03)

BDL(<0.

003)

BDL(<

0.003) 0.003

28 Total Arsenic as As mg/l APHA 22nd Edition -3114 B BDL(<

0.01)

BDL(<

0.01)

BDL(<

0.01)

BDL(<

0.01)

BDL(<

0.01) 0.01

29 Cyanide as CN mg/l APHA 22nd Edition -4500 CN BDL(<

0.05)

BDL(<

0.05)

BDL(<

0.05)

BDL(<

0.05)

BDL(<

0.05) 0.05

30 Lead as Pd mg/l APHA 22nd Edition -3111 B BDL(<

0.01)

BDL(<

0.01)

BDL(<

0.01)

BDL(<

0.01)

BDL(<

0.01) 0.01

31 Zinc as Zn mg/l APHA 22nd Edition -3111 B 0.214 0.123 0.17 0.21 0.14 5

32 Hexavalent Chromium as

Cr6+ mg/l APHA 22nd Edition -3500 Cr B

BDL(<0.0

1) BDL(<0.01)

BDL(<0.0

1)

BDL(<0.

01)

BDL(<

0.01) Not Specified

33 Total Chromium as Cr mg/l APHA 22nd Edition -3111 B BDL(<

0.02)

BDL(<

0.02)

BDL(<

0.02)

BDL(<

0.02)

BDL(<

0.02) 0.05

34 Nickel as Ni mg/l APHA 22nd Edition -3111 B BDL(<

0.02)

BDL(<

0.02)

BDL(<

0.02)

BDL(<

0.02)

BDL(<

0.02) 0.02

35 Sodium Absorption Ratio _ Calculation 6.47 5.60 2.52 1.15 0.61 Not Specified

36 Salinity %0 APHA 22nd Edition -2520 B 0.9 0.6 0.5 0.2 0.3 Not Specified



Rev. No. 02


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102


CaCO3 mg/l IS:3025:Part-40:(Reaff:2014) 50 40 110

68 60 Not Specified

38 Magnesium Hardness as

CaCO3 mg/l APHA 22nd Edition -3500 Mg B 170 80 100

56 50 Not Specified

39 Molybdenum as Mo mg/l APHA 22nd Edition -3111 D BDL(<

0.05)

BDL(<

0.05)

BDL(<

0.05)

BDL(<

0.05)

BDL(<

0.05) 0.07

40 Total Coliform

MPN/

100m

l

IS :1622 (1981) 280 140 60

23

50 Absent

41 Faecal coliform

MPN/

100m

l

IS:1622 (1981) 9 9 9

4

11 Absent

TABLE – 3.12 (c): SURFACE WATER ANALYSIS RESULT

S.No Parameters Unit Procedure SW11

SW12 SW13 SW14

Acceptable

Limit as per

IS 10500:2012

1 Colour Hazen APHA 22nd Edition

(Reaff:2012) 3

12

12 25 5



Rev. No. 02


Chapter No. 03

103

2 Temperature °C APHA 22nd Edition

(Reaff:2012) 25.7

25.8

25.1 25.4 Not Specified

3 pH at 25°C - IS : 3025 Part 11- 1983

(Reaff:2012) 7.52

7.05 7.25 7.06 6.5-8.5

4 Electrical

Conductivity μS/cm

IS : 3025 Part 14- 1984 (Reaff:

2012) 378

568 2220 789

Not Specified

5 Turbidity NTU IS : 3025 Part 10-1984 (Reaff:

2012) 1.9

5.2 8.2 7.6

1

6 Total Dissolved

Solids mg/l

IS : 3025 Part 16-1984 (Reaff:

2012) 251

318 1288 442

500

7 Total Hardness as

CaCO3 mg/l

IS : 3025 Part 21-2009 (Reaff:

2014) 128

122 450 160

200

8 Total Alkalinity as

CaCO3 mg/l

IS : 3025 Part 23- 1986

(Reaff:2012) 176

171 391 177

200

9 Chloride as Cl mg/l IS : 3025 Part 32-1988 (Reaff:

2014) 32

61 407 101

250

10 Sulphate as SO4 mg/l APHA 22nd Edition -4500-

SO42- E 16

21 120 48

200

11 Fluoride as F mg/l APHA 22nd Edition-4500-F

B&D 0.59

0.46 0.54 0.58

1



Rev. No. 02


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104

12 Nitrate as NO3 mg/l APHA 22nd Edition -4500-

NO3- B BDL(< 1)

1 14 13

45

13 Ammonical Nitrogen mg/l APHA 22nd Edition -4500- NH3

B&C 0.13

0.36 0.22 0.26

Not Specified

14 Total Nitrogen as N mg/l APHA 22nd Edition -4500-

N&C,NO3 E 1.42

1.21 8.21 6.97

Not Specified

15 Total Phosphorous mg/l IS : 3025 Part 31-1988

(Reaff:2014) 0.02

0.26 0.08 0.49

Not Specified

16 Sodium as Na mg/l IS : 3025 Part 45-1993

(Reaff:2014) 45

53 282 70

Not Specified

17 Potassium as K mg/l IS : 3025 Part 45-1993

(Reaff:2014) 11

25 22 39

Not Specified

18 Calcium as Ca mg/l IS : 3025 Part 40-1991

(Reaff:2014) 27

25 108 42

75

19 Magnesium as Mg mg/l APHA 22nd Edition-3500 Mg-B 14 15 44 14 30

20 Iron as Fe mg/l IS : 3025 Part 53-2003 0.74 1.61 2.07 2.96 1

21 Manganese as Mn mg/l APHA 22nd EDN -3500-Mn D BDL(< 0.02)

0.07

0.05

BDL0.

09(<

0.02) 0.10

22 Dissolved Oxygen as

O2 mg/l

IS:3025:Part-38:1989

(Reaff:2003) 5.7

4.9 6.1 5.1

Not Specified



Rev. No. 02


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105

23 Chemical Oxygen

Demand mg/l

IS:3025:Part-58:2006

(Reaff:2012) 32


24

Bio-Chemical

Oxygen Demand @

27°C for 3 days

mg/l IS:3025:Part-44:1993

(Reaff:2014) 5.2

5.4

2.7 4.1 Not Specified

25 Copper as Cu mg/l APHA 22nd Edition -3111 B BDL(< 0.03) BDL(< 0.03) BDL(<

0.03)

BDL(<

0.03) 0.05

26 Mercury as Hg mg/l APHA 22nd Edition -3112 B BDL(<0.001) BDL(<0.001) BDL(<

0.001)

BDL(<

0.001) 0.001

27 Cadmium as Cd mg/l APHA 22nd Edition -3111 B BDL(<0.003) BDL(<0.003) BDL(<

0.003)

BDL(<

0.003) 0.003

28 Total Arsenic as As mg/l APHA 22nd Edition -3114 B BDL(< 0.01) BDL(< 0.01) BDL(<

0.01)

BDL(<

0.01) 0.01

29 Cyanide as CN mg/l APHA 22nd Edition -4500 CN BDL(< 0.05) BDL(< 0.05) BDL(<

0.05)

BDL(<

0.05) 0.05

30 Lead as Pd mg/l APHA 22nd Edition -3111 B BDL(< 0.01) BDL(< 0.01) BDL(<

0.01)

BDL(<

0.01) 0.01

31 Zinc as Zn mg/l APHA 22nd Edition -3111 B 0.24 0.63 0.25 0.17 5

32 Hexavalent

Chromium as Cr6+ mg/l APHA 22nd Edition -3500 Cr B BDL(< 0.01)

BDL(< 0.01) BDL(<

0.01)

BDL(<

0.01) Not Specified



Rev. No. 02


Chapter No. 03

106

33 Total Chromium as

Cr mg/l APHA 22nd Edition -3111 B

BDL(< 0.02) BDL(< 0.02) BDL(<

0.02)

BDL(<

0.02) 0.05

34 Nickel as Ni mg/l APHA 22nd Edition -3111 B BDL(< 0.02) BDL(< 0.02) BDL(<

0.02)

BDL(<

0.02) 0.02

35 Sodium Absorption

Ratio _ Calculation 1.74

2.06 5.77 2.38 Not Specified

36 Salinity %0 APHA 22nd Edition -2520 B 0.3 0.3 1.3 0.5 Not Specified


CaCO3 mg/l IS:3025:Part-40:(Reaff:2014) 68


38 Magnesium

Hardness as CaCO3 mg/l APHA 22nd Edition -3500 Mg B 68


39 Molybdenum as Mo mg/l APHA 22nd Edition -3111 D BDL(< 0.05) BDL(< 0.05) BDL(<

0.05)

BDL(<

0.05) 0.07

40 Total Coliform MPN/

100ml IS :1622 (1981) 240

900 170 500 Absent

41 Faecal coliform MPN/

100ml IS:1622 (1981) 23

80 23 50 Absent



Rev. No. 02


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107

3.9.6 Observations

Ground Water

The pH value of the collected ground water in the study area found to be in the range from 7.57 to 8.01


range from 480 mg/L to 1512 mg/ L. Total alkalinity is found to be the range from 250 mg/L to 330 mg/L



and magnesium values were ranged from 43 mg/L to 104 mg/L and 27 mg/L to 73 mg/L respectively. Iron

content observed in the range from BDL (<0.05) mg/l to 0.3 mg/l. Most of the metals are observed as

below the detection limit. Total Coliforms were observed up to 26 MPN/100ml and Faecal Coliforms were

observed <2 MPN/100ml at all locations.

Surface Water

The pH value of the collected surface water in the study area found to be in the range from 6.61 to 7.52


range from 184 mg/L to 1288 mg/ L. Total alkalinity is found to be the range from 121mg/L to 391mg/L


from32 mg/L to 407 mg/L and Sulphate values were observed from 8 mg/L to 120 mg/L. The Calcium

and magnesium values were ranged from 16 mg/L to 108 mg/L and 12.5 mg/L to 46 mg/L respectively.

Iron content found in the range from 0.26 mg/L to 5.46 mg/l. COD values observed in the range from 12

mg/l to 60 mg/l. Most of the metals are observed to be within the detection limit. Total Coliforms were

observed from 17 MPN/100ml to 900 MPN/100ml and Fecal Coliforms were observed from 4 MPN/100ml

to 80 MPN/100ml.



Rev. No. 02


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108

GW-1 FATEPURA GW- 3 SURAJ

GW-4 KHERVA GW-5 RUPAL

GW-6 LAGNAJ GW-7 LINCH

Figure 3.20 Ground Water Sampling locations



Rev. No. 02


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109

SW-1 LODRA SW-2 RIDROL

SW-5 RUPAL SW-8 KADI (NARMADA CANAL)

SW-12 UDALPUR SW-14 MANSA

Figure 3.21 Surface Water Sampling locations



Rev. No. 02


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110

3.10 Soil Quality

To study the soil quality of the region, sampling locations were selected to assess the existing soil

conditions in and around the project area representing various land use conditions. The physical and

chemical concentrations were determined.

The present study of the soil quality establishes the baseline characteristics of soil and this will help in

future in identifying the incremental concentration changes if any, due to the operation in the proposed

project.

3.10.1 Sampling and Analysis Techniques

Soil samples were collected from three different depths viz., 30cm, 60cm, and 100cm below the surface.

The samples were analyzed for physical and chemical characteristics. The samples have been analyzed

as per the established scientific methods for physio-chemical parameters.

3.10.2 Details of Soil Sampling Locations

Soil samples were collected at eight (8) locations as tabulated in Table 3.13.

TABLE 3.13: SOIL SAMPLING LOCATIONS

Location Code Name of the Location Coordinates

Latitude Longitude

S1 Dholasan 23°24'15.21"N 72°20'31.35"E

S2 Ridrol 23°27'52.92"N 72°40'22.25"E

S3 Fatepura 23°25'50.10"N 72°38'11.60"E

S4 Kherva 23°32'40.63"N 72°26'39.67"E

S5 Lagnaj 23°27'2.82"N 72°29'56.61"E

S6 Rupal 23°41'8.83"N 72°20'29.62"E

S7 Susar 23°38'52.11"N 72°13'41.66"E

S8 Linch 23°29'43.65"N 72°22'17.26"E

The study area map covering the Soil Sampling Locations is enclosed as Figure – 3.26



Rev. No. 02


Chapter No. 03

111

Soil Sampling Stations

Figure – 3.22: Map showing Soil Sampling Stations

3.10.3 Presentation of Results

The soil quality at the specified location during the study period is tabulated as Table-3.14

TABLE 3.14 (a)- Soil Analysis Results

S.No Parameters Test Method S1 S2 S3 S4

1 pH (1:5 Suspension) IS -2720(Part 26) 1987

(RA 2016) 7.03

6.84 6.49

6.96

2 Moisture, % IS -2720(Part 2)

1987(RA 2015) 0.98

1.31 1.08

1.18

3 Porosity, % IS -2720 (Part 36) 32.1 36.4 30.8 28.8



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4 Water Holding

Capacity,%

Soil Chemical Analysis

By M. L. Jackson 32.6

35.1 32.8

25.8

5 Permeability, cm/hr Soil Chemical Analysis

By M. L. Jackson 1.7

1.3 1.8

1.2

6 Cation Exchange

Capacity, m.eq/100g

IS -2720(Part 24) (RA

2015) 12.6

18.7 24.8

26.9

7 Electrical conductivity,

mS/cm (1:5 Suspension)

IS -14767:2000 (RA

2016) 0.246

0.142 0.672

0.078

8 Exchangeable Calcium

as Ca, m.eq/100g

FAO Chapter 3,

ABCTL/SOIL/SOP 4 4.51

9.85 35.5

33.1

9 Exchangeable Magnesiu

m as Mg, m.eq/100g

FAO Chapter 3,


7.3 10.7

12.15

10 Exchangeable Sodium as

Na, m.eq/100g

FAO Chapter 3,


4.15 5.28

10.3

11 Potassium as K, Kg/ha FAO Chapter 3,

ABCTL/SOIL/SOP 7 1852

1688 1618

1892

12 Texture Classification IS -2720(Part 26)

1987(RA 2011)

Silt

Loam

Silty

Clay

loam

Loam

Clay

Loam

13 Sand (%)

Robinson Pipette Method

24.1 18.4 32.4 27.2

14 Clay (%) 21.6 24.6 28.6 35.1

15 Silt (%) 54.3 57 39 37.7

16 Sodium Absorbtion ratio Calculation 6.35 4.49 3.48 6.85

17 Available phosphorus as

P, kg/ha FAO Chapter 3, ABCTL/SOIL/SOP2 13.7

20.7

17

41.8

18 Available Nitrogen as N,

kg/ha FAO Chapter 3, ABCTL/SOIL/SOP11 236

207

263

310

19 Total Nitrogen as N,

kg/ha IS-14684:1999, Reaff:2008 309

271

352

407



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TABLE 3.14 (b)- Soil Analysis Results

S.No Parameters Test Method S5 S6 S7 S8

1 pH (1:5 Suspension) IS -2720(Part 26) 1987

(RA 2016) 7.48 6.89 6.53 6.73

2 Moisture, % IS -2720(Part 2) 1987(RA

2015) 1.05 1.36 1.2 1.47

3 Porosity, % IS -2720 (Part 36) 26.8 34.1 36.6 26.8

4 Water Holding Capacity,% Soil Chemical Analysis By

M. L. Jackson 19.6 31.8 36.9 14.4

5 Permeability, cm/hr Soil Chemical Analysis By

M. L. Jackson 2 0.23 0.21 0.41

6 Cation Exchange Capacity,

m.eq/100g

IS -2720(Part 24) (RA

2015) 21.8 32.8 30.7 9.66

7 Electrical conductivity,

mS/cm (1:5 Suspension) IS -14767:2000 (RA 2016) 0.606 0.343 0.508 0.107

8 Exchangeable Calcium as

Ca, m.eq/100g

FAO Chapter 3,

ABCTL/SOIL/SOP 4 41.7 7.06 12 154

9 Exchangeable Magnesium a

s Mg, m.eq/100g

FAO Chapter 3,

ABCTL/SOIL/SOP 5 12.1 12.25 14.3 11.92

10 Exchangeable Sodium as

Na, m.eq/100g

FAO Chapter 3,

ABCTL/SOIL/SOP 6 10.7 5 8.82 7.61

11 Potassium as K, Kg/ha FAO Chapter 3,

ABCTL/SOIL/SOP 7 3649 1816 2102 1809

12 Texture Classification IS -2720(Part 26) 1987(RA

2011) Loam Clay Clay

Sandy

Loam

13 Sand (%)

Robinson Pipette Method

27.1 25.8 29.6 55.6

14 Clay (%) 26.8 51.8 47.6 17.1

15 Silt (%) 46.1 22.4 22.8 27.3

16 Sodium Absorbtion ratio Calculation 6.53 5.10 7.70 2.64



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Source: ABC Techno Labs India Private Limited

3.10.4 Observations:

It has been observed that the pH of the soil is ranging from 6.49 to 7.48 while the soil texture is shown in

figure 3.27. Moisture found in the range from 0.98 to 1.47%. Conductivity of the soil ranges from 0.078

to 0.672 mS/cm. Texture of the soil in the selected locations of study area were found to be Silty Loamy

to Sandy Loamy in nature. The potassium content varies from 1618 to 3649 kg/ ha. Exchangeable

Sodium content varies from 4.15 to10.3 m.eq/100g. Exchangeable calcium and Exchangeable

magnesium were found in the range between 4.51 to 154 m.eq/100g & 7.3 to 14.3 m.eq/100g

respectively.

Figure 3.23: Particle Size distribution of soil sample

The infiltration rate of the soil depends on the soil texture of the area. Soil texture depends on the relative

proportion of Sand, Silt and Clay. In Mehsana area predominant soil group is of Loamy soil. It has been

observed that infiltration rate in the loamy soil is high.

0

20

40

60

S-1 S-2 S-3 S-4 S-5 S-6 S-7 S-8

Val

ue(

%)

Soil Samples

Particle Size distributionSand (%)Clay (%)Silt (%)

17 Available phosphorus as P,

kg/ha FAO Chapter 3, ABCTL/SOIL/SOP2 36.9 54.7 41.8 21.8

18 Available Nitrogen as N,

kg/ha FAO Chapter 3, ABCTL/SOIL/SOP11 284 346 294 255

19 Total Nitrogen as N, kg/ha IS-14684:1999, Reaff:2008 391 505 399 375



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S1-DHOLASAN S3-FATEPURA

Soil 4-KHERVA Soil 6-RUPAL

Soil 7-SUNSAR Soil 8-LINCH

Figure 3.24 Soil Sampling locations of the study area



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3.11 Biological Environment

3.11.1 Introduction

Natural flora and fauna are important features of the environment. They are organized into natural

communities and are sensitive to outside influences. Integrating ecological thinking into the planning

process is urgent need in the context of deterioration of natural environments, which is unwanted but

direct consequence of development. Biological communities, being dependent on the condition and

resources of its location may change if there is change in the environment. Hence change in the status

of flora fauna are an elementary requirement of Environment Impact Assessment Studies, in view of the

need for conservation of environmental quality and biodiversity. Information on flora fauna was collected

within the study area.

3.11.2 Reconnaissance of Study Area

The study area is dominated by scrub, small trees and a few large trees along with agricultural fields. The

study area has been defined as an area covering the buffer distance of 10 km around each mining

lease.The field observations on vegetation was made by surveying at different locations with the help of

“Flora of Gujarat by G. L. Shah, flora, topographic maps, forest working plan identification of those plants

which form dominant vegetation, native plants which prevails flowering period. Actual counts of birds

were made following the standard survey technique. Observation were made during a walk through in

the chosen transect for sighting birds and animals. The number of animals and birds observed in 1km

stretch of the site were directly counted and listing was made. Birds were noted and identified with the

help of binocular and standard field identification guides. Other animals were directly counted from

amongst the vegetation, bushes and roadside fields. Flora fauna detail and other Agriculture information

has been collected during the study period.

3.11.3 Assessment of Flora

The list of floral species is prepared based on visual observation during site visit and through review of

site literature and secondary data available with various government offices is referred for identifying rare

or endangered species in the region.

Documents

Draft Environment Impact Assessment Report For Onshore Oil