Asian Consulting Engineers Pvt. Ltd. New Delhi...Asian Consulting Engineers Pvt. Ltd. New Delhi...

ADANI WELSPUN EXPLORATION LIMITED (AWEL)

Environmental Impact Assessment for Offshore Oil & Gas Development and Production from Discovered Small Field of B-9 Cluster Offshore Fields at Mumbai Offshore Basin. Final EIA Report.

Asian Consulting Engineers Pvt. Ltd. New Delhi

October 2018

Rev-04

EIA Report - Offshore Oil & Gas Development and Production from Discovered Small Field of B-9 Cluster Offshore Fields at Mumbai Offshore Basin.

Asian Consulting Engineers Pvt. Ltd.

QUALITY CONTROL PLAN

Project Title EIA Report - Offshore Oil & Gas Development and Production from Discovered Small Field of B-9 Cluster Offshore Fields at Mumbai Offshore Basin.

Client Adani Welspun Exploration Limited (AWEL).

Contact Person Mr. Arvind Hareendran, Vice President.

Document Prepared By Asian Consulting Engineers Pvt Ltd., India.

Original Date Prepared 04.07.2018.

Revision 1 Date 15.09.2018.




Approved By:

09.10.2018

(EIA Coordinator) (Date)

By signing, I certify, that the document/report has been prepared and reviewed as per the quality assurance measures established in Asian Consulting Engineers Pvt Ltd, (ACE) “Quality Management System”.


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TABLE OF CONTENTS

QUALITY CONTROL PLAN EXECUTIVE SUMMARY CHAPTER-1: INTRODUCTION 1.1 INTRODUCTION………………………………………………………………………………........... 1-1 1.2 NEED OF THE EIA STUDY …………………………………………………………...…………….. 1-4 1.3 PROJECT PROPONENT …………………………………………………………...…………………. 1-6 1.4 EIA CONSULTANT……………………………………………………….……………………....…… 1-6 1.5 POLICY AND LEGAL FRAMEWORK …………………………………………………………...…. 1-6 1.6 SCOPE OF THE EIA STUDY …………………………………………………………...……………. 1-7 1.7 APPROACHES AND METHODOLOGY OF EIA STUDY…………………………………….......... 1-10 1.8 STRUCTURE OF THE EIA REPORT…………………………………………………………...…….. 1-10

CHAPTER-2: PROJECT DESCRIPTION 2.1 PROJECT OVERVIEW………………………………………………………………………..…...… 2-1 2.2 PROJECT LOCATION …………………………………..………………………………………....... 2-5 2.3 PROJECT DESCRIPTION ……………………………………………………………......................... 2-6

2.3.1 Details of Proposed Pipelines………………………………………………………………… 2-6 2.3.2 Gas and Oil Processing ………………………………………………………………………. 2-8 2.3.3 Overall Indicative Production Profile for B-9 Field.................................................................... 2-8 2.3.4 Electrical Systems……………………………………………………………………………… 2-10 2.3.5 Telecommunication System......................................................................................................... 2-10 2.3.5.1 VSAT System ............................................................................................................. 2-11 2.3.5.2 CCTV System ............................................................................................................. 2-11 2.3.6 Software…................................................................................................................................... 2-11 2.3.7 Supply Base….............................................................................................................................. 2-11 2.3.8 Staffing......................................................................................................................................... 2-12

2.4 RESOURCE UTILIZATION ................................................................................................................... 2-12 2.4.1 Water Requirement .................................................................................................................... 2-12 2.4.2 Power Requirement .................................................................................................................... 2-12

2.5 NOISE, AIR EMISSIONS, EFFULENTS, AND SOLID WASTE GENERATION ………………….. 2-13 2.5.1 Noise............................................................................................................................................ 2-13 2.5.2 Emission….................................................................................................................................. 2-13 2.5.3 Effluents and Solid Waste…....................................................................................................... 2-13 2.5.4 HSE Requirement….................................................................................................................... 2-14

CHAPTER-3 : DESCRIPTION OF THE ENVIRONMENT 3.1 INTRODUCTION…………………………………………..………………………………...………..... 3-1 3.2 ENVIRONMENTAL BASELINE ………………………..………………………………...…………... 3-3 3.3 APPLICABILITY OF COASTAL REGULATION ZONE (CRZ) ………………………..…………… 3-3 3.4 GEOLOGY OF MUMBAI OFFSHORE BASIN ………………………..………………………………. 3-5 3.5 CLIMATE AND METEOROLOGY ………………………..………………………………...……….. 3-6

3.5.1 Mean Sea Surface Temperature ………………………………………..........…………………. 3-6 3.5.2 Mean Air Temperature ………………………..………………………………...…………….. 3-7 3.5.3 Mean Wind Speed ………………………..………………………………...…………………. 3-7 3.5.4 Waves and Tides ………………………..………………………………...…………………… 3-8 3.5.5 Rainfall ………………………..………………………………...……………………………… 3-9 3.5.6 Cyclones ………………………..………………………………...…………………………… 3-9 3.5.7 Circulation ………………………..………………………………...………………………….. 3-10

3.6 MARINE ENVIRONMENT ………………………..………………………………...………………… 3-10 3.6.1 Sampling Methodology ………………………..………………………………...……………. 3-10 3.6.1.1 Sea Water Sampling………………………………..……………………………….. 3-10 3.6.1.2 Sea Sediments Sampling…..………………………..……………………………….. 3-18 3.6.1.3 Marine Biological Characteristics ………………………..………………………… 3-22


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3.6.1.4 Marine Fisheries……………………………………………………………………. 3-34

CHAPTER-4: ANTICIPATED IMPACTS AND MITIGATION MEASURES 4.1 IDENTIFICATION AND ASSESSMENT OF IMPACTS……….…….………….……………....…… 4-1 4.2 INTERACTION OF PROJECT ACTIVITIES WITH THE ENVIRONMENT……………………...... 4-2

4.2.1 Impact on Air Environment........................................................................................................ 4-3 4.2.2 Impact on Noise Quality ............................................................................................................ 4-4 4.2.3 Impact on Marine Water Quality .............................................................................................. 4-4 4.2.4 Impact on Sediment Quality ..................................................................................................... 4-5 4.2.5 Impact on Marine Biological Quality ........................................................................................ 4-5 4.2.6 Socio-Economic Environment .................................................................................................. 4-5

4.3 IMPACT EVALUATION........................................................................................................ ................. 4-6 4.4 IMPACT SIGNIFICANCE ...................................................................................................................... 4-6 4.5 IMPACT MITIGATION MEASURES .................................................................................................... 4-7

4.5.1 Air Environment ........................................................................................................................ 4-7 4.5.2 Water Environment ................................................................................................................... 4-8 4.5.3 Biota .......................................................................................................................... ................ 4-8 4.5.4 Occupational Health Hazard from Noise Pollution ................................................................. 4-8 4.5.5 Noise due to Drilling Activities ................................................................................................ 4-8 4.5.6 Waste Generation and Management ......................................................................................... 4-9

CHAPTER-5: ENVIRONMENTAL MONITORING PLAN 5.1 INTRODUCTION …………………………………………………….…….………….…….…...……. 5-1 5.2 ENVIRONMENTAL MONITORING PLAN ......................................................................................... 5-1 5.3 BUDGET ............................................................................................................................. ..................... 5-4

CHAPTER-6: ADDITIONAL STUDIES 6.1 INTRODUCTION ............................................................................................................................. ...... 6-1 6.2 RISK ASSESSMENT .............................................................................................................................. 6-1

6.2.1 Risk Analysis .............................................................................................................................. 6-2 6.2.2 Identification of Hazards in Offshore Oil and Gas Field Development..................................... 6-2 6.2.3 Major Hazards ............................................................................................................................ 6-3 6.2.4 Hazards- Nature and sensitivity of impact zones ........................................................................ 6-5

6.3 CONTROL MEASURES FOR MAJOR IDENTIFIED HAZARDS……………………………….….. 6.7 6.4 DISASTER MANAGEMENT PLAN AND EMERGENCY ACTION PLAN ………………………. 6-9

6.4.1 Emergency Classification ................................................................................................... ....... 6-10 6.4.2 Emergency Action Plan .............................................................................................................. 6-10 6.4.2.1 Instrumentation and Safety System ........................................................................... 6-10 6.4.2.2 Telecommunication System ..................................................................................... 6-14

6.5 PLATFORM ARRANGEMENT & STRUCTURE ................................................................................. 6-15 6.6 HEALTH, SAFETY AND ENVIRONMENT (HSE) .............................................................................. 6-16

CHAPTER-7: PROJECT BENEFITS 7.1 PROJECT BENEFITS ……………………………………………………………............................... 7-1

CHAPTER-8: ENVIRONMENTAL MANAGEMENT PLAN 8.1 STRUCTURE OF EMP……………………………………………………………………………........ 8-1 8.2 PROPOSED ENVIRONMENTAL MITIGATION MEASURES…………………………………........ 8-1 8.3 ENVIRONMENTAL MANAGEMENT PLAN……………………………………………………........ 8-4

8.3.1 Waste Management Plan ............................................................................................................ 8-9 8.3.2 Oil Spill Contingency Plan ......................................................................................................... 8-10

8.4 CAPITAL AND RECURRING COST FOR POLLUTION CONTROL MEASURES ……………….. 8-12 8.5 ENVIRONMENTAL AWARENESS TRAINING .................................................................................. 8-12 8.6 ENVIRONEMENT MANAGEMENT CELL .......................................................................................... 8-12


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CHAPTER-9: SUMMARY AND CONCLUSION 9.1 INTRODUCTION …………………………………………………………………………………...... 9-1 9.2 SUMMARY…………………………………………………………………………………………..... 9-1 9.3 CONCLUSION……………………………………………………………………………………........ 9-1

CHAPTER 10: DISCLOSURE OF CONSULTANTS ENGAGED 10.1 INTRODUCTION................................................................................................................. .................. 10-1 10.2 QUALITY OF SERVICES....................................................................................................................... 10-1 10.3 AREA OF SPECIALIZATION................................................................................................................ 10-1 10.4 RESOURCES........................................................................................................................................... 10-2

LIST OF ANNEXURES Annexure No. Title

Annexure I Form 1 and Pre-Feasibility Report (PFR). Annexure II HSE’s Policy. Annexure III Vessel Pictures and Documents. Annexure IV ODAG Clearance Documents. Annexure V Demobilization Letter to FODAG from Adani. Annexure VI ODAG Inspection Pictures. Annexure VII GPS Data Log.

LIST OF TABLES

Table No. Title Page No.

Table 1.1 Salient Features of Project....................................................................................... ............... 1-2 Table 1.2 Expected Production from B-9 Clusters …………………....................................…………. 1-4 Table 1.3 Applicable Acts and Guidelines for the Proposed Project …………………………………. 1-6 Table 1.4 Compliance Report: Adherence to ToR Approved by MoEF&CC for the EIA Study ……. 1-12 Table 2.1 Project Details ……………………………………………………………........................... 2-1 Table 2.2 Proposed Products ………………………………………………………………………….. 2-2 Table 2.3 Block-Boundary Co-ordinates.……………………………………………………………… 2-5 Table 2.4 Well-Head Coordinates.…………………………………………………………………… 2-5 Table 2.5 Pipelines Specification……………………………………………………………………… 2-7 Table 2.6 Field Parameters ……………………………………………………………………………. 2-7 Table 2.7 Production Profile of B-9 Field…………………………………………………………….. 2-8 Table 2.8 Details of Platform Facilities ………………………………………………………………. 2-9 Table 3.1 Reservoir Rock in the Mumbai Offshore Basin ……………………………………………. 3-5 Table 3.2 Specifications of Sea Water (SW) Sampling Locations …………………………………… 3-11 Table 3.3 Preservation of Water Samples ……………………………………………………………. 3-11 Table 3.4 Marine Water Quality Analysis ……………………………………………………………. 3-16 Table 3.5 Specifications of Sea Sediment (SS) Sampling Locations ………………………………… 3-21 Table 3.6 Preservation of Sediment Samples ………………………..……………………………….. 3-21 Table 3.7 Offshore Marine Sediment Quality Analysis ………………………..…………………….. 3-22 Table 3.8 Marine Biological Environment Analysis ………………………..……………………….. 3-29 Table 3.9 Abundance of Zooplankton Species ………………………..……………………………… 3-30 Table 3.10 Abundance of Phyto-Plankton Species………………………..……………………………. 3-30 Table 3.11 Abundance of Benthic Species ………………………..………………………………........ 3-32 Table 3.12 List of Fish Species in the Study Area……………………………………………………… 3-34 Table 4.1 Interaction Matrix for the Propsed Project …………………………………………………. 4-2 Table 4.2 Impact Significance Criteria ………………………………………………………………… 4-7 Table 4.3 Potential Environmental Impacts of Proposed Activities (Without Mitigation Measures) … 4-7 Table 4.4 Potential Environmental Impacts of Proposed Activities (With Mitigation Measures) ……. 4-9 Table 5.1 Environmental Monitoring Program ………………………………………………………. 5-2 Table 5.2 Budget for Environmental Monitoring Plan during Drilling/Installation …...……………… 5-4


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Table 5.3 Budget for Environmental Monitoring Plan during Operation Phase ………………………. 5-5 Table 8.1 Proposed Environmental Mitigation Measures …………………………………………..… 8-1

Table 8.2 Environmental Management Plan – Mitigation Management Matrix (during drilling phase) ………………………………………………………………………………………. 8-5

Table 8.3 Waste Management Plan ....................................................................................................... 8-9 Table 8.4 Environmental Budget …………………………………………………………………….. 8-12 Table 8.5 Environmental Management Cell .......................................................................................... 8-13

LIST OF FIGURES

LIST OF PHOTO PLATES

Photo Plate No. Title Page No.

Photo Plate 2.1 A Typical Jack-Up Rig …………………………………………………………………. 2-9 Photo Plate 3.1 Marine Water Sampling ………………………..………………………………...…….. 3-12 Photo Plate 3.2 Sediment Sample Collection from Mumbai Offshore Basin …………………………… 3-17 Photo Plate 3.3 Ecological Sample Collection from Mumbai Offshore Basin …………………………… 3-19

LIST OF ABBREVIATIONS

Abbreviations AWEL Adani Welspun Exploration Limited BOD Biological Oxygen Demand BOP Blowout Preventer CO Carbon Monoxide COD Chemical Oxygen Demand CPCB Central Pollution Control Board CRZ Costal Regulation Zone DG Diesel Generator DGH Director General of Hydrocarbon

Figure No. Title Page No.

Figure 1.1 B-9 Cluster Field Location Map................……………………………………………….. 1-3 Figure 1.2 Study Area around B-9 Cluster Field Location (15 km Buffer) ……………………......... 1-5 Figure 2.1 Project Location from the nearest cities.…………………………..................…………... 2-3 Figure 2.2 Proposed Project Location and other AWEL Blocks.……………………………………. 2-4 Figure 2.3 Conceptual Sub-Sea Pipeline Layout Plan for B-9 DSF.………………………………… 2-6 Figure 3.1 Project Location…………………..………………………………...…………………….. 3-2 Figure 3.2 Nearest cities to the Project Location ………………………..…………………………… 3-4 Figure 3.3 Sea Surface Temperatures ………………………..………………………………………. 3-6 Figure 3.4 Wind Speed and Wind Direction ………………………..……………………………….. 3-7 Figure 3.5 Windrose for the months of February to May 2018 ………………………..……………. 3-8 Figure 3.6 Cyclone Prone Area ………………………..………………………………...…………… 3-9 Figure 3.7 Sea Water Sampling Location with Vessel Route ………………………..……………… 3-12 Figure 3.8 Sea Water Sampling Locations within Study Area………………………………………. 3-13 Figure 3.9 A Typical NISKIN Sampler ……………………….………………………………......... 3-14 Figure 3.10 Sea Sediment (SS) Sampling Location and Vessel Route ………………………………… 3-19 Figure 3.11 Sea Sediment (SS) Sampling Location and Vessel within Study Area…………………... 3-20 Figure 3.12 Typical Van-Veen Grab Sampler ………………………………………………………… 3-21 Figure 3.13 Chlorophyll Content in Mumbai Offshore Basin …………………………………………. 3-24 Figure 3.14 Graphical Analysis of Marine Biological Characteristics ………………………………... 3-34 Figure 4.1 Methodology for Environmental Impact Assessment …………………………………….. 4-1 Figure 6.1 Risk Matrix and Acceptability Criteria ……………………………………………… 6-2 Figure 6.2 Risk Categories and Significance Criteria ............................................................. 6-3


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DMP Disaster Management Plan DSF Discovered Small Field EAC Expert Appraisal Committee EPIC Engineering, Procurement, Installation & Commissioning ERP Emergency Response Plan ESD Emergency Shut-Down FGS Fire and Gas Detection System GPS Global Positioning System HIPPS High Integrity Pressure Protection System IS Indian Standard IUG Instrument Utility Gas KLD Kilo Liters per Day MODU Mobile Offshore Drilling Unit MoEF&CC Ministry of Environment, Forest and Climate Change MPN Most Probable Number ONGC Oil and Natural Gas Corporation ODAG Offshore Defense Advisory Group PM Particulate Matter PLC Programmable Logic Controller RSC Revenue Sharing Contract RTU Remote Telemetry Unit SAR Search and Rescue SDP Shut Down Panel SS Sea Sediment SSSV Subsurface Safety Valve TDS Total Dissolved Solids TOR Terms of Reference TSS Total Suspended Solids VSAT Voice and Data Communication VOC Volatile Organic Compound WBM Water-Based Drilling Mud

EEXXEECCUUTTIIVVEE SSUUMMMMAARRYY


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EXECUTIVE SUMMARY

1. INTRODUCTION

Adani Welspun Exploration Limited (AWEL) is a joint venture E&P Company formed by two India based multinational business conglomerates Adani Group based out of Ahmedabad and Welspun Group based out of Mumbai, to undertake upstream Oil & Gas business with 65% and 35% shares respectively. AWEL has been awarded contract area MB/OSDSF/B9/2016 comprising of B-9 Cluster Offshore Fields and has signed the Revenue Sharing Contract (RSC) with the Government of India (GoI). The field was originally discovered by Oil and Natural Gas Corporation (ONGC) which was subsequently offered for bidding under Discovered Small Fields (DSF) round, 2016. AWEL plans to develop the B-9 Cluster field by drilling wells and installing offshore facilities to produce natural gas and crude oil. The B-9 cluster comprises three (3) DSF offshore fields namely B-9, B-7 (Gas Fields) and BRC (Oil Field). The project envisages development drilling and installation of well-head platforms and sub-sea pipelines in the Mumbai Offshore Basin. Consequently, it involves identification of the potential environmental impacts of the project and suggestion of mitigation plan.

2. PROJECT DESCRIPTION

Drilling operations shall be carried out at B-9 clusters offshore fields to extract the trapped hydrocarbons. The gas and oil produced from the wells will be commingled and sent to ONGC’s C-24 wellhead platform located nearly 80 km from the project site via 80 km sub-sea pipelines. The processing of the oil and gas is envisaged to be done through existing offshore platforms operated by ONGC. The proposed project does not include any facilities or installations that pass through the Coastal Regulatory Zone (CRZ). Facilities existing beyond the CRZ will be used for evacuation of hydrocarbons.

The salient features of the proposed project are elaborated in Table 1 below.

Table 1: Project Brief

Items Details

Project Name Development of B-9 Cluster Offshore Fields in the Discovered Small Field (DSF), Mumbai Offshore Basin

Project Category ‘A’ Location Mumbai Offshore Basin (located beyond 12 nautical miles)

Project Fields

Three Discovered Small Fields (DSF) a. B-9 138.5 sq.km Gas Field b. B-7 22.7 sq.km Gas Field c. BRC 22.03 sq.km Oil Field

Total Number of Proposed Production Wells

12 Wells a. B-9 Field Well Well Head Platform 1 (B-9-1 Area)

Surface Location of 4 wells



Items Details Well Head Platform 2 (B-9-3 Area)


b. B-7 Field Well Well Head Platform 3 Surface Location of 3 wells

c. BRC Field Well Well Head Platform 4 Surface Location of 2 wells

Type of Hydrocarbon Expected

Oil & Gas

Type of Rig to be Used Jack-Up Rig

Depth of Wells 2500 m to 4000 m Total Vertical Depth (TVD) Wells may be deviated with horizontal displacement of around 1500 m

Drilling Period 45 - 60 days per well Test Flaring of Gas 4 days per well during initial testing.

Proposed Drilling Fluid Water-based Mud System Synthetic Oil Based Mud (SOBM) may be used as an option.

Drill Cuttings (during drilling)

About 300– 500 m³ per well

Total Length of Proposed Sub- Sea Pipelines

Laying of approx. 130 km sub-sea pipelines

Proposed Pipeline Facility

a. Approx. 80 km sub-sea pipeline (upto 10”) from B-9 field to a nearby existing platform

b. Approx. 10 km intra-field sub-sea pipeline (upto 8”) within the B-9 area

c. Approx. 30 km sub-sea pipeline (upto 8”) from B-7 platform/ area to B-9 platforms /area

d. Approx. 10 km sub-sea pipeline (upto 6”) from BRC platform/area to B-7 platform /area or B-9 platforms/ area

Nearest Railway Station Nearest Airport

Railway Station: Delwada (Gujarat) – approx. 74 km Airport: Diu Airport (Daman and Diu) – approx. 72 km

Nearest Town /City/ Village

Town: Diu (Daman and Diu) - approx. 72 km City: Jafrabad (Gujarat) - approx. 75 km Village: Delvada (Gujarat) - approx. 74 km

Expected Cost of the Project

Tentatively INR 1600 Crores.

3. DESCRIPTION OF ENVIRONMENT

This chapter presents an overview of the existing environmental aspects related to the development of B-9 cluster offshore fields in the discovered small fields (DSF) in the Mumbai Offshore Basin. The knowledge of the characteristics of the local biological environment allows an understanding of the potential impacts on the marine environment, thereby adopting relevant control measures to mitigate the adverse negative impacts.

The state of the environment has been characterized on various marine components in the project site and its surrounding areas. The project site comprises of 3 DSF, i.e., B-9, B-7 and BRC fields in the Mumbai offshore basin, wherein B-9 and B-7 are Gas fields and BRC is an



Oil field. The study area pertains to 15 km radial distance from each of the three (3) DSFs and proposed pipelines

3.1 MET-OCEAN CONDITIONS OF MUMBAI OFFSHORE REGION

Mumbai Offshore basin is located on the western continental shelf of India between Saurashtra basin in NNW and Kerala Konkan in the south.

Meteorological Data

Climate

Mumbai offshore region has a tropical wet and dry climate under the Koppen climate classification1. The region does not experience distinct seasons, but the climate can broadly be classified into two main seasons—the humid season and the dry season. Usually, the period between October to May is relatively dry. The region gets southwest monsoon rains beginning June to end September with peak rains occurring in July. Occasionally, northeast monsoon showers occur in October and November.

A. Mean Sea Surface Temperature

According to the National Oceanic and Atmospheric Administration (NOAA), the maximum and minimum value of mean sea surface temperature in the Arabian Sea is of the order of 30.8ºC and 26.04 ºC, respectively.

B. Mean Air Temperature

As per available data with Physical Sciences Division, Earth System Research Laboratory, NOAA, Boulder, Colorado,maximum and minimum value of mean air temperature in the Arabian Sea is of the order of 30.2ºC and 24.04 ºC, respectively.

C. Mean Wind Speed

The study of average hourly wind speed in project area shows significant seasonal variation over the course of the year. The windier part of the year lasts for 2.9 months, from June 1st to August 30th, with average wind speeds of more than 10.6 miles per hour.

D. Waves and Tides

As per available data with Physical Sciences Division, Earth System Research Laboratory, NOAA, Boulder, Colorado, Predominant significant wave height and zero-crossing period are 50 to 70 cm and 8 to 8.5 sec respectively. The predominant wave periods and wave heights are 5-6 sec and 0.5 to 1.5 m respectively during the fair-weather season (October-May) and 5-9 sec and 1-3 m respectively during the rough weather season (June-September). A wide range of wave heights 0.5-5 m occurs during the rough season.

3.1 MARINE ENVIRONMENT

Water and sediment quality sampling was carried out in B-9, B-7 and BRC blocks of the cluster offshore fields in the Mumbai Offshore Basin. The samples collected were further considered for laboratory analysis.

Sampling Methodology

A survey vessel scrutinized by Offshore Défense Advisory Group (ODAG) was hired for offshore sampling. The vessel was well-equipped with Global Positioning System (GPS) and

1 City Profile of Greater Mumbai, 2011.

https://www.ndrdgh.gov.in/NDR/Images/MumbaiOffshore/MumbaiOffshore.jpg



Radar for accurate positioning, radio communication and satellite telephone for communication. The survey vessel was cruised to the sampling locations according to the given geographical coordinates, i.e., latitude and longitude of the sampling locations. The water and sediment samples were drawn from 2 levels in the sea, i.e., at the surface and bottom levels for each of the five (5) sampling locations.

i. Sea Water Sampling

The sea water (SW) samples were collected from two (2) levels in the sea using a NISKIN Sampler of 5 litres capacity. The depth levels are as follows:

a. Sample 1 – 3 m below the surface b. Sample 2 - Few meters above the sea bed c. Results of Sea Water Monitoring

i. The observed pH value in the study region during the period of study is in the range of 8.0 to 8.2. The changes in pH are marginal as expected for natural marine waters sustaining low primary productivity. The total hardness (as CaCO₃) in all the water sample lies in the range of 8000 to 10000 mg/L. The value of alkalinity (as CaCO₃) was in the range of 126 to 132 mg/l.

ii. The dissolved oxygen ranges from 4.4 mg/l to 5.2 mg/l i.e. as iii. The concentrations of Chloride in all the sample were in the range of 18135 to 20419

mg/L. The contents of oil & grease in all sample was below detectable limit (BDL) in all the sampling locations.

iv. The BOD levels in all water samples was found to be below detection limit (BDL) wherein the detection limit for BOD is 2 mg/L.

v. It has been observed from the laboratory analysis that residual free chlorine, Cr⁶+, and as were below detection limits in all the water samples. Whereas, there has been observed a slight detection in few samples in regard to the concentration of lead, nickel, zinc and mercury.

ii. Sea Sediments Sampling

Marine sediments play a very important role as repositories of organic matter and nutrients for the ecosystem but at the same time, they are vulnerable to heavy metal and organic toxics (from anthropogenic activities) especially in the offshore oil and gas.

Five (5) sea sediment (SS) samples were collected from the Mumbai Offshore Basin.

Results of Sea Sediment Monitoring

Oil and grease ranges from 0.1 to 0.7, Nitrite as Nitrogen found as 3 mg/kg at location SS1& SS5 rest of the location shown the values below detection limits.

The Total Kjeldahl Nitrogen ranges from 403 mg/kg to 528 mg/kg.

The hexavalent chromium is found below the detection limit at all the locations.

Among the heavy metals, iron varied from 39,243 mg/kg to 56,797 mg/kg and lead from 5 to 7 mg/kg, zinc showed variation of 60 to 69 mg/kg, cadmium was found below detection limit and arsenic varied from 2.3 mg/kg to 4.2 mg/kg.

Among the exchangeable nutrient fractions of nitrogen, nitrite was the least one and varied from 0.19 to 0.31μmol/kg.

The polyaromatic compounds are found ranges from 0.23 mg/kg to 1.12 mg/kg.



iii. Marine Biological Characteristics

Marine environment is known to support vast population of organisms, found distributed in both pelagic and benthic realms. Most of the organisms of the pelagic realm constitute the plankton. Phytoplankton and zooplankton together constitute this community and form the primary food source for most of the marine species. Their response to physio-chemical characteristics of the water column determines their distribution, abundance, and production.2 The occurrence of marine species both plants and animals has largely been controlled by the physio-chemical properties of ocean water.

Analysis Results

The location-wise abundance of the various species of phytoplankton, zoo planktons, benthic meio and the chlorophyll productivity has been observed.

2 Jeffrey, S.W. and Hallegreff, G.M., 1990. Phytoplankton ecology in Australian waters. In: Clayton, M.N. and King, R.J. (Eds.]. Biology of Marine Plants, Longman — Cheshire, Melbourne. pp: 310-348.



Table 3.7: Marine Biological Environment Analysis

S. No. Parameters Unit SS1 at B9-1 SS2 at B9-2 SS3 at B9-3 SS4 at B7 SS5 at BRC

S B S B S B S B S B

1. Chlorophyll-a mg/m³ 2.72 2.85 2.91 2.81 3.04 1.91 3.49 1.95 6.81 6.39

2. Primary Productivity- Gross mgC/m³/d 680 -- 640 -- 490 -- 600 -- 490 --

3. Primary Productivity- Net mgC/m³/d 190 -- 120 -- 150 -- 70 -- 80 --

4. Phyto-plankton No./ml 199.6 100 190.8 76 189.8 181.4 287.6 247 932.4 519.8

5. Zooplankton No./500 ml 62 -- 64 -- 39 -- 37 -- 48 --

6. Benthic Meio No./m -- 25 -- 19 -- 12 -- 60 -- 17



4. ANTICIPATED IMPACTS AND MTIGATION MEASURES

This chapter of the EIA report discusses the identification as well as assessment of potential impacts due to the proposed project on the environment and proposes suitable measures to mitigate the identified potential adverse impacts. The information presented in these chapters facilitates the identification of the interactions between the planned construction and operation phases with the environment. The anticipated impacts and mitigation measures are tabulated in Table 2 below, the anticipated impacts and mitigation measures for both the phases, i.e., Drilling and Installation phases are identical.

Table 2: Proposed Environmental Mitigation Measures

S. No.

Component Impact Mitigation Measures

Drilling and Installation Phase 1. Marine

Water Quality

• Displacement of sea-bed sediments may lead to anoxic intertidal and offshore mud, leading to the local chemical changes in water quality

• Water quality may be affected by the solid/liquid discharge and accidental spillage of chemicals

• The sewage shall be treated on-board of the rig and installation barges according to the MARPOL Regulations. Residual chlorine of the treated sewage shall not exceed 1mg/L before disposal

2. Marine Sediment

• Activities like deployment of rigs and other sub-sea infrastructure may cause local and temporary disturbance to the sea-bed

• The layout of the subsea infrastructure shall be designed to avoid sea bed features considered to be geo-hazards

3. Marine Ecology

• Adverse impact on marine life due to drilling activity, noise generation, effluent discharge

• All precautionary measures shall be adopted to minimize disturbance to the marine animals due to deployment and operations of offshore wells

4. Air Environment

• NOx, PM₁₀, and Sox emissions from venting, flaring and D.G. Sets

• Good operational controls and high level of monitoring shall be built into the design operations

• Regular maintenance of engines and DG sets shall be ensured.

• The existing and proposed DG sets shall comply with the applicable emission norms

5. Noise Environment

• Noise and Vibrations from the heavy machineries - large power generation units, diesel engines, fluid

• Mobile noise sources such as rig, and vessels shall be re-routed to avoid disturbances

• Avoid loud, sudden noises,



S. No. Component Impact Mitigation Measures

pumps and mud pumps, equipment and transportation vehicles

wherever possible. Integral noise shielding shall be used where practicable and applicable

6. Socio-Economic

• Employment generation • People from local area to be employed during construction

7. Occupational Health and Safety

• Respiratory disease due to inhalation of dust

• Auditory ailment due to noise

• Occupational hazards such as accidental falls, fire hazards, etc.

• The use of personal protective equipment like ear muffs and dust mask shall be made stringent

• Water sprinkling system for fugitive dust generating areas

• Safety training to workers • Regular health check-ups for

workers/ employees Operation Phase 1. Marine

Water • The water quality of the

project site may get affected due to accidental spillage of chemicals/oil/lubricants from the operational activities

• Usage of only low toxicity chemicals must be ensured on-board of the rig and transportation vessels

• Adequate well management shall be ensured during well completion activities to minimize produced water production

2. Marine Sediment

• Sediment quality is less likely to be affected due to operational discharges and accidental spillage of fuel/chemical/lubricant during the project activities


3. Marine Ecology

• Sub-sea infrastructure shall act as a physical hindrance to the marine organisms leading to direct habitat loss

• The operational activities are also likely to have an impact on the benthos in the benthic zone

• All precautionary measures shall be adopted to minimize disturbance to the marine animals due to deployment and operations of offshore platforms and pipelines

4. Air • Air emissions may result from gas flaring activities during the well testing only (1-2 days)

• The DG sets shall comply with the applicable emission norms

• Regular maintenance of the transportation vessels

• Regular ambient air quality



S. No. Component Impact Mitigation Measures

monitoring must be carried out 5. Noise and

Vibration • Noise is likely to be

generated during the operation phase due to the operation of rigs, generators, etc.

• Rubber padding/noise isolators shall be provided at equipment/machineries

• Regular maintenance of all equipment and transportation vessels shall be ensured


• Generation of dust, grit, and emissions during operations leading to chronic health problems


• Strict enforcement of PPEs on workers/ employees

• Safety training to workers • Cordoning of hazardous areas as

‘No Smoking Zone’ • Bi-annual or annual health check-

up camps for workers/ employees

5. ENVIRONMENTAL MONITORING PLAN

An Environmental Monitoring Plan has been included which outlines the monitoring parameters, frequency, and monitoring locations against specific mitigation measures. The plan clearly defines the responsibilities for mitigation and monitoring and suggests time bound schedules. The parameters and respective frequency of monitoring as part of Environmental Monitoring Plan for drilling and operation phases are tabulated below in Table 3 and Table 4 respectively.

Table 3: Environmental Monitoring Program (Drilling and Installation Phase)

Receptor Location Monitoring and Reporting Frequency

Natural Resource

Project Site (Operation areas) Daily during Drilling

Drilling wastes Drilling Locations

• Daily monitoring & recording of quantity

• Monitor and record the generation quantity on daily basis

Oil Spills

Drilling Locations

Daily during Drilling Operation

Noise & Vibration

Project Site (Operation areas)

Weekly during Drilling and Installation phase

Water Quality

• Upto 1 km radius from Drilling location/Wellhead platform site

• At every 5 km stretch of the sub-sea pipeline and locations within 1 km radius of the pipeline

Once during Drilling and Installation phase

Sediment Quality


• At every 5 km stretch of the sub-sea




pipeline and locations within 1 km radius of the pipeline

Ecological Parameters




Table 4: Environmental Monitoring Program (Operation) Phase

Receptor Location Monitoring and

Reporting Frequency

Water Quality

• Upto 1 km radius Well/Wellhead platform site


Once in a year

Sediment Quality



Once in a year




Once in a year

6. ADDITIONAL STUDIES

The risk assessment study is aimed at identifying the potential sources which pose risks of a hazard outbreak, determining the probability of such hazard occurrences and their consequences. In doing so, the risk assessment exercise mitigates the severity of any accident and facilitates preparation of an effective emergency response plan or disaster management plan. Risk assessment includes the identification of risks involved in the drilling activities and the associated activities in the drilling program, platform & pipeline installation activities along with the assessment of probability of certain consequences.

7. PROJECT BENEFITS

The world consumes 12000 million tons of oil equivalent (mtoe) of energy resources, whereas India consumes 4.4% of the world’s total (524.2 mtoe) according to FICCI. Of the total primary energy consumption basket, oil and gas constitute 45% share in the total energy basket mix. About 78 per cent of India’s petroleum consumption is met from imports (mostly of crude oil), while about 25% of natural gas (including LNG) consumption comes from imports. It is estimated that in the upcoming years, the import dependency for crude oil alone would reach above 90% level.



Thus, development of existing oil and gas reserves has become a necessity to bridge the rising demand-supply gap, reduce import dependency and make ourselves resilient to the external factors of economic and political disruptions in the sourcing nations.

8. ENVIRONMENTAL MANAGEMENT PLAN (EMP)

The Environmental Management Plan is prepared to facilitate the field level implementations. EMP is a key to ensure a safe and clean environment. The desired results from the environmental mitigation measures proposed in the project may not be obtained without a management plan to assure its proper implementation and function. The EMP envisages the plans for the proper implementation of mitigation measures to reduce the adverse impacts arising out of the project activities. This plan needs to be well implemented during drilling and installation as well as operation phases of the project. The following plans are proposed under the Environmental Management Plan:

• Waste Management Plan • Oil Spill Contingency Plan

9. SUMMARY AND CONCLUSION

EIA study includes establishment of the present environmental scenario in the proposed project area. EIA report consists of study of the specific activities related to the project and evaluation of the probable environmental impacts, thus leading to the recommendations of necessary mitigation measures. The entire EIA study has been carried out based on the applicable environmental legislation, regulations and guidelines of the MoEF&CC.

The project involves offshore O&G development and production from DSF of B-9 cluster fields of 183.23 sq.km at Mumbai Offshore Basin.

In the drilling and installation phase the vehicular & vessel movement, pipe-laying works and operating of generators will have maximum impact, especially on air, noise, vibration and ecological environment. Water quality and geology/soil will be affected due to the discharge of wastewater (construction and domestic) and any leakage of oil etc.; from generators and other equipment. On the other hand, during the operation phase; usage of maintenance & cleaning chemicals and risk of gas leakages will affect the water, air, noise and biological environment. With respect to occupational health, impacts are anticipated on the health of the employees during drilling and installation phase. Personnel working near the noise generating machines and handling of chemicals and lubricants are more susceptible of getting health hazards and the effect of these will be minimized through various mitigation measures. Overall, this project will bring economic benefits, increase energy security of the country and generate employment opportunities.

10. DISCLOSURE OF CONSULTANTS ENGAGED

Asian Consulting Engineers (ACE) Pvt. Ltd., New Delhi is the EIA consultant for this proposed project. ACE is a QCI-NABET accredited independent EIA consultant organization (Certificate No.: NABET/EIA/1417/SA030) for various sectors including preparation of EIA of onshore and offshore oil and gas exploration and development and transportation of oil and gas through pipelines (Category A). ACE has been awarded ISO 9001:2015 certification by RINA.

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Asian Consulting Engineers Pvt. Ltd. 1-1

1. INTRODUCTION

1.1 INTRODUCTION

Adani Welspun Exploration Limited (AWEL) is a joint venture E&P Company formed by two India based multinational business conglomerates Adani Group and Welspun Group to undertake upstream Oil & Gas business with 65% and 35% shares respectively. AWEL has been awarded contract area MB/OSDSF/B9/2016 comprising of B-9 Cluster Offshore Fields and has signed the Revenue Sharing Contract (RSC) with the Government of India (GoI). The field was originally discovered by Oil and Natural Gas Corporation (ONGC) which was subsequently offered for bidding under Discovered Small Fields (DSF) round, 2016. AWEL plans to develop the B-9 Cluster field by drilling wells and installing offshore facilities to produce natural gas and crude oil, and process through the existing offshore facilities. The B-9 cluster comprises three (3) DSF offshore fields namely B-9, B-7 and BRC.

The scope of the proposed development project comprises of the following:

• Drilling and completion of 12 Wells out of which 7 wells are in B-9 field, 3 wells in B-7 & 2 wells in BRC fields.

• Installation of two (2) wellhead platforms in B-9 area, and one (1) platform each in B-7 & BRC areas. Alternately, sub-sea completion wells may also be explored during the design stage.

• Laying of approximately 80 km sub-sea pipeline (upto 10”) from B-9 field to a nearby operator’s existing well head platform and hooking-up with the offshore platform facilities.

• Laying of approximately 10 km intra-field sub-sea pipeline (upto 8”) within the B-9 area and hooking-up with the existing offshore facilities.

• Laying of approximately 30 km sub-sea pipeline (upto 8”) from B-7 platform/area to B-9 platforms /area and hooking-up with the platform facilities.

• Laying of approximately 10 km sub-sea pipeline (upto 6”) from BRC platform/area to B-7 platform /area or B-9 platforms/area and hooking-up with the platform facilities.

The B-9 & B-7 are Gas fields, whereas BRC is an Oil field. The development drilling & completion work are planned to be performed using a Jack-Up Rig at the Wellhead Platform. The overall development cost tentatively is expected to be about US$ 250 million (INR 1600 Crores). Table 1.1 below presents the salient features of the project.

The location map of the B-9 Cluster Field is shown in Figure 1.1.

11



Table 1.1: Salient Features of the Project

Items Details Project Development of B-9 Cluster Offshore Fields in the Discovered Small

Fields (DSF), Mumbai Offshore Basin

Project Fields Three DSF Fields a. B-9 – Gas Field: 138.5 sq.km

b. B-7 – Gas Field: 22.7 sq.km c. BRC – Oil Field: 22.03 sq.km

Location Mumbai Offshore Basin (located beyond 12 nautical miles) Project Activities 1. Drilling and Completion of Wells: 12 nos.

a. 7 wells in B-9 Fields b. 3 wells in B-7 fields

c. 2 wells in BRC field

2. Installation of Wellhead Platform: 4 nos. a. 2 in B-9 Field b. 1 in B-7 Field c. 1 in BRC Field

3. Laying of Subsea Pipelines: 130 km (approx.) a. Approx. 80 km sub-sea pipeline (up to 10”) from B-9 field to

a nearby ONGC platform b. Approx. 10 km intra-field sub-sea pipeline (up to 8”) within

the B-9 area c. Approx. 30 km sub-sea pipeline (up to 8”) from B-7

platform/ area to B-9 platforms /area d. Approx. 10 km sub-sea pipeline (up to 6”) from BRC

platform/ area to B-7 platform /area or B-9 platforms/ area


Oil and Gas.

Type of Rig to be Used

Jack-Up Rig.

Depth of Wells 2500 m to 4000 m Total Vertical Depth (TVD). Wells may be deviated with horizontal displacement of around 1500m.

Study Area Details • Located beyond 12 nautical miles, well beyond CRZ, thus the project is not covered under the CRZ Notification, 2011.

• No human settlement (within 15 km of the project area). • No Eco-Sensitive Zone (within 15 km of the project area). • No Development activities on land.

Total Project Cost INR 1600 Cr.



Figure 1.1: B-9 Cluster Field Location Map



The expected hydrocarbon production from the three DSF fields (B-9 Cluster Fields) is presented in below Table 1.2:

Table 1.2: Expected Production from B-9 Clusters

Sl. No. Products Quantity 1. Gas (B-9 Field): 32 mmscfd

(peak production rate for a plateau period of 4 years followed by declining profiles)

2. Gas (B-7 Field): 21 mmscfd (peak production rate for a plateau period of 4 years followed by declining profiles)

3. Oil (BRC Field): 800 bopd & 0.4 mmscfd (peak production rate for a plateau period of 2 years followed by declining profiles)

Mmscfd: Million standard cubic feet per day BOPD: Barrels of oil per day

1.2 NEED OF THE EIA STUDY

The purpose of proposed project is development and production of oil and gas fields at Mumbai offshore basin. As per the list of project or activities requiring prior environmental clearance given in the EIA Notification issued by MoEF & CC on 14 September 2006, proposed project is listed on S No. 1 (b) and requires Environmental Clearance from MoEF & CC.

An application for Environmental Clearance was submitted to MoEF&CC vide letter dated 12 December 2017 and the approval of Terms of Reference (TOR) for the EIA study was issued by MoEF&CC vide letter No. J-11011/565/2017-IA. II (I) dated 13th March 2018.

The location of the proposed project is beyond 12 nautical miles (NM) and falls in the Mumbai Offshore Basin. The EIA study area is taken as 15 km radial distance from each block (as the 10 km buffer was not covering the entire block). There are no eco-sensitive areas or biodiversity hotspots within 15 km of the fields. The nearest habitation is in Diu located about 72 km from the field. The map of study area around 15 km distance from the project location is shown in Figure 1.2.



Figure 1.2: Study Area around B-9 Cluster Field Location (15 km Buffer)



1.3 PROJECT PROPONENT

Adani Welspun Exploration Limited (AWEL)is a joint venture (JV) E&P Company formed by two India based multinational business conglomerates to undertake Oil and Gas business, namely:

i. Adani Group (Ahmedabad). ii. Welspun Group (Mumbai).

In this JV, Adani Group holds 65% through its flagship company Adani Enterprises Limited (AEL) whereas Welspun Group holds 35% through Welspun Natural Resources Pvt. Ltd, a subsidiary of its flagship company Welspun Enterprises Limited (WEL). Both these enterprises are enlisted on various Stock Exchanges. AWEL holds key operated and non-operated assets in Mumbai Offshore & Gulf of Kutch in the Western Offshore Basin. It has carried oil and gas exploration programmes in India and across borders.

1.4 EIA CONSULTANT

Adani Welspun Exploration Limited (AWEL) proposes for the development of B-9 cluster offshore fields. In line with the industry’s best practices and the regulatory obligations on environmental protection, AWEL has proposed to conduct EIA for the project, engaging Asian Consulting Engineers (ACE) Private Limited as the EIA consultant.

ACE is Quality Council of India-National Accreditation Board for Education and Training (QCI-NABET) accredited EIA consulting organisation (Certificate No.: NABET/EIA/1417/SA030) for varied sectors including offshore and onshore oil and gas exploration, development, production & oil and gas transportation pipelines. ACE is an ISO 9001:2015 certified company.

1.5 POLICY AND LEGAL FRAMEWORK

The Project Proponent will ensure that the project aligns with all the National legislations, regulations, and conventions, relating to various aspects of Offshore Oil and Gas Development and Production activities in India. Table 1.3 shows list of applicable Acts and Rules as set by MoEF&CC and Central Pollution Control Board (CPCB).

Table 1.3: Applicable Acts and Guidelines for the Proposed Project

Issues Applicable Legislation Water

1) The Environment Protection Act, 1986 – Standards for liquid discharge by Oil Drilling and Gas Extraction Industry as notified vide notification dated GSR 176 (E) April 1996.

Air

2) The Environment Protection Act, 1986 – Guidelines for discharge for gaseous emissions by Oil Drilling and Gas Extraction industry as notified vide notification dated GSR 176 (E) April 1996.

3) The Environment (Protection) Second Amendments Rules, 2002 – Emission Standards for New Generator Sets.

Hazardous Substances and Wastes

4) Hazardous and Other Wastes (Management and Transboundary Movement) Rules, 2016.

5) Guidelines for disposal of solid wastes by Oil Drilling and Gas Extraction industry as notified, vide notification dated GSR 546 (E)



Issues Applicable Legislation August 2005.

6) The Petroleum Act, 1934. Safety and Protection against Pollution of Environment

7) Oil Mines Regulations, 1984. 8) Oil Field (Regulation and Development) Act 1948 and the Petroleum

& Natural Gas Rules, 1959 and amendments. 9) MARPOL Convention, 1973/78 for preventing and minimizing

pollution from ships-both accidental pollution and that from routine operations.

10) International Convention for the Safety of Life at Sea (SOLAS), 1973, as amended for safety of vessels.

11) Coast Guard Act, 1950 for combating marine pollution and security of the maritime zones of India.

EIA 12) Environmental Protection Act 1986 and its amendments. 13) EIA notification 2006 and its amendments.

1.6 SCOPE OF THE EIA STUDY

The scope of the EIA study includes detailed characterization of the existing status of the water and biological environment within the block area, identification of the potential environmental impacts of the project and formulation of an effective environmental management plan (EMP) to prevent, control & mitigate the adverse environmental impacts of the project, thereby ensuring environmental compliance. The Terms of Reference (TOR) for this project were approved by the Ministry of Environment, Forest and Climate Change (MoEF&CC) vide F.No. J-11011/565/2017-IA II (I) dated 13th March 2018 as given below:

It is seen from the approved TOR by MoEF&CC that the Expert Appraisal Committee (EAC) has recommended the standard TOR applicable for offshore and onshore drilling projects. Table 1.4 below highlights the compliance framework adhering to the approved and standard TOR by MoEF&CC for the preparation of the EIA study reports.



1.7 APPROACH AND METHODOLOGY OF EIA STUDY

i. Approach of EIA Study

The EIA study includes establishment of the present environmental scenario in the project area. EIA report consists of study of the specific activities related to the project and evaluation of the probable environmental impacts, thus leading to the recommendations of necessary mitigation measures. The entire EIA study is carried out based on the applicable environmental legislations, regulations and guidelines of the MoEF&CC.

ii. Establishment of Baseline Environmental Status

A comprehensive database on the baseline environmental status/conditions of the study area has been established through review, compilation & analysis of:

i) Existing published secondary data/literature/information, and ii) Primary data collection through field study, surveys and monitoring.

iii. Field Study/ Monitoring for Generation of Primary Data

The collected secondary data has been appropriately supplemented by conducting the necessary primary data generation/ collection through field study/monitoring. The field monitoring has been carried out as per the guidelines of the Central Pollution Control Board (CPCB) and requirements of the MoEF&CC.

a) Marine Water Quality: Five (5) samples of sea water were collected from two (2) levels of water column surface (3m below the surface and few meters above the sea-bed) using NISKIN Samplers of 5 litres capacity. These were analysed to assess the quality of marine water in the project area.

b) Marine Sediment Quality: Sea sediment samples were collected using a Van-Veen Grab Sampler and analysed from five (5) sediment sampling (SS) representative locations from the study area.

c) Biological Ecology: Zooplankton, Phytoplankton and Benthos species present at five (5) representative locations were identified and their abundance was calculated. Secondary information on other marine species were collected, reviewed and presented.

1.8 STRUCTURE OF THE EIA REPORT

This draft EIA report is organized in the following chapters:

Chapter 1: Introduction gives a brief description about the project portfolio, project proponent and environmental legislations/permits applicable to the project. It also highlights the approved Terms of Reference (ToR) for the Environmental Impact Assessment (EIA) Study.

Chapter 2: Project Description provides the operations associated with the project along with the need and justification of the project.

Chapter 3: Description of the Environment describes the background environmental characteristics and the other socio-economic activities in the area.

Chapter 4: Identification of Impacts and Mitigation Measures presents the potential environmental impacts and recommends the cost-effective mitigation



measures to counter the negative impacts of the project activities.

Chapter 5: Environmental Monitoring Plan describes the mechanism to address the adverse environmental impacts during different phases of the project along with frequency and the sampling locations.

Chapter 6: Additional Studies illustrates the Risk Assessment & Disaster Management Plan highlighting an emergency action plan for prior preparedness in case of an emergency related to the project activities.

Chapter 7: Project Benefits details out the positive outcomes of the project in accordance to the socio-economic as well as environmental parameters.

Chapter 8: Environmental Management Plan provides a mechanism to address and mitigate the adverse impacts of the project.

Chapter 9: Summary and Conclusion provides a synopsis of the major findings of the EIA study and delineates the conclusion drawn out of the study.

Chapter 10: Disclosure of Consultants Engaged provides the details about the consultant’s organization and the nature of consultancy engaged in to carry out the EIA study.



Table 1.4: Compliance Report Adherence to ToR Approved by MoEF&CC for the EIA Study

S. No. Terms of Reference (ToR) Reference in the EIA Report

Chapter No.

Section No.

Page No. Title/Remarks

1. Executive Summary of the Project. Enclosed with the EIA report. 2. No. of development wells for which environmental clearance is

accorded and No. of new wells proposed during expansion. Status and No. of wells which are completed and closed.

2 2.1, 2.2 & 2.3

2-1 to 2-6 The detailed description of the project along with the salient features, no. of wells, no. of well head platforms are given.

3. Project Benefits. 7 7.1 7-1 The Benefits of the project is given. 4. Cost of project and period of completion. 2 2.1 2.1 to 2.2 Project overview. 5. Employment to be generated 6. Distance from coast line. 1 1.2 1-4 Nearest distance from the coastline is

approximately 72 km (aerial distance). 7. Details of sensitive areas such as coral reef, marine water park,

sanctuary, and any other eco-sensitive area 1, 3 1.2 1-4 There is no eco sensitive areas around 15

km distance from the project location. 8. Recommendation of SCZMA/CRZ clearance as per CRZ

Notification dated 6th January 2011 (if applicable). CRZ is not applicable as the project is located beyond 12 nautical miles. Nearest Landfall point is approximately 72 km (aerial distance).

9. Details on support infrastructure and vessel in the study area. Not available currently. 10. Climatology and meteorology including wind speed, wave and

currents, rainfall, etc. 3 3.5 3-5 -

11. Details on establishment of baseline on the air quality of the areas immediately affected by the development drilling and also particularly with reference to hydrogen sulphide, sulphur dioxide, NOx and background levels of hydrocarbons and VOCs

- - - -

12. Details on estimation and computation of air emissions (such as nitrogen oxides, sulphur oxides, carbon monoxide, hydrocarbons, VOCs, etc.) resulting from flaring, DG sets, combustion, etc. all project phases.

- - - -




Chapter No.

Section No. Page No. Title/Remarks

13. Baseline data collection for surface water for one season leaving the monsoon season within 1 km for each development well, particularly in respect of oil content in the water sample and sediments sample.

3 3.6 3-9 to 3-19

-

14. Fisheries study w.r.t. benthos and marine organic material and coastal fisheries.

3 3.6 3-29 The fish species found in the study area are mentioned.

15. Source of fresh water and detailed water balance, waste water generation and discharge.

2 2.1 2-1 -

16. Noise abatement measures and measures to minimize disturbance due to light and visual intrusions in case of project site closed to the coast.

4, 5, 8 4.5, 4.5.2

4-7 The project location is far from the nearest coast (72 kms.). The mitigation measures are suggested to minimize the impacts of noise pollution.

17. Procedure for handling oily water discharges from deck washing, drainage systems, bilges, etc.

8 8.2.3 8-10 The waste management plan along with oil spill contingency plan is provided.

18. Procedure for preventing spills and spill contingency plans. 8 8.2.3 8-10 The waste management plan along with oil spill contingency plan is provided.

19. Procedure for treatment and disposal of produced water. 2 2.5.3, 2-20 The appropriate measures for treatment and disposal of produced water are provided.

20. Procedure for sewage treatment and disposal and also for kitchen waste disposal.

2 & 8 2.5.3, 8.3.1

2-20, 8-9 The waste management plan is given for treatment and disposal of sewage waste, kitchen waste.

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

2, 8 2.1, 2.5.3, 8.3.1

2-1, 2-20, 8-9

The details of solid wastes to be generated are given along with its proper treatment and disposal measures.

22. Storage of chemicals on site. 8 - - The measures are given for safe storage.




Chapter No.

Section No. Page No. Title/Remarks

23. Commitment for the use of water-based mud (WBM) and synthetic oil-based mud in special case.

2 2.1 2-1 The Water-based mud will be used, Synthetic oil based mud will be kept as an option in special cases.

24. Details of blowout preventer installation. Blow out preventer is an integral part of a drilling rig and will be installed before spud of every well. Details are rig specific. Rig charter is still underway.

25. Risk assessment and mitigation measures including whether any independent reviews of well design, drilling and proper cementing and casing practices will be followed.

4 & 6 - The Risk assessment is incorporated in the report.

26. Handling of spent oils and oil from well test operations. 8 - - The oil spill contingency plan is provided to handle the spent oil/oil spills to be generated in the project activity.

27. Details of all environment and safety related documentation within the company in the form of guidelines, manuals, monitoring programmes including Occupational Health Surveillance Programme etc.

- - - Company HSE’s policy is annexed as Annexure II.

28. Restoration plans and measures to be taken for decommissioning of the rig and restoration of onshore support facilities on land.

- - - Not applicable.

29. Documentary proof for membership of common disposal facilities, if required.

- - - Not applicable.

30. Any litigation pending against the project or any directions/order passed by any Court of Law against the project. If so, details thereof.

- - - No litigation pending.

31. Total capacity and recurring cost for environmental pollution control measures.

8 8.4 8-11 The capital cost and recurring cost is provided.

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PROJECT DESCRIPTION

2.1 PROJECT OVERVIEW

Adani Welspun Exploration Limited (AWEL) has been awarded the Offshore Contract Area MB/OSDSF/B9/DSF (B-9) Cluster and has signed the Revenue Sharing Contract (RSC) with the Government of India. AWEL intends to fast-track the project to produce the ‘first-gas’ from the field at the earliest.

The contract area MB/OSDSF/B9/2016 comprises of three (3) Discovered Small Fields (B-9, B-7 and BRC), located in the Mumbai Offshore Basin. While B-9 & B-7 are Gas Fields, BRC is an Oil Field. Well-Head platforms are aimed to be minimum facilities platforms which will be unmanned with periodical visits through helicopter to conduct routine maintenance, well maintenance and any other related repair work. The project details has been tabulated in the Table 2.1 below.

Table 2.1: Project Details

Items Details

Project Name Development of B-9 Cluster Offshore Fields in the Discovered Small Field(DSF), Mumbai Offshore Basin

Project Category ‘A’ Location Mumbai Offshore Basin (located beyond 12 nautical miles) Project Fields Three Discovered Small Fields (DSF)

a. B-9 138.5 sq.km Gas Field b. B-7 22.7 sq.km Gas Field c. BRC 22.03 sq.km Oil Field

Total Number of Proposed Production Wells

12 Wells a. B-9 Field Well Well Head Platform 1 (B-9-1 Area)


Well Head Platform 2 (B-9-3 Area)


b. B-7 Field Well Well Head Platform 3 Surface Location of 3 wells

c. BRC Field Well Well Head Platform 4 Surface Location of 2 wells


Oil & Gas

Type of Rig to be Used Jack-Up Rig

Depth of Wells 2500 m to 4000 m Total Vertical Depth (TVD). Wells may be deviated with horizontal displacement of around 1500 m.

Drilling Period 45 - 60 days per well.

22



Items Details Test Flaring of Gas 4 days per well during initial testing.

Proposed Drilling Fluid Water-based Mud System. Synthetic Oil Based Mud (SOBM) may be used as an option.

Drill Cuttings (during drilling)

About 300– 500 m³ per well.

Total Length of Proposed Sub- Sea Pipelines

Laying of approx. 130 km sub-sea pipelines.

Proposed Pipeline Facility

a. Approx. 80 km sub-sea pipeline (upto 10”) from B-9 field to a nearby existing ONGC platform.

b. Approx. 10 km intra-field sub-sea pipeline (upto 8”) within the B-9 area.

c. Approx. 30 km sub-sea pipeline (upto 8”) from B-7 platform/ area to B-9 platforms /area.

d. Approx. 10 km sub-sea pipeline (upto 6”) from BRC platform/area to B-7 platform /area or B-9 platforms/ area

Nearest Railway Station Nearest Airport.

Railway Station: Delwada (Gujarat) – approx. 74 km. Airport: Diu Airport (Daman and Diu) – approx. 72 km.

Nearest Town /City/Village

Town: Diu (Daman and Diu) - approx. 72 km City: Jafrabad (Gujarat) - approx. 75 km Village: Delvada (Gujarat) - approx. 74 km

Expected Cost of the Project

Tentatively INR 1600 Crores.

Figure 2.1 & 2.2 depicts the project location map along with the distance from the nearest city.

The project involves offshore O&G development and production from DSF of B-9 cluster fields of 183.23 sq.km at Mumbai Offshore Basin. The proposed products/utilities are mentioned in Table 2.2.

Table 2.2: Proposed Proucts

S. No Products Quantity 1. Gas (from B-9 Field) 32 mmscfd

(Peak Production Rate (PPR) for a plateau period of four (4) years followed by declining profiles).

2. Gas (from B-7 Field) 21 mmscfd (PPR for a plateau period of four (4) years followed by declining profiles).

3. Oil (from BRC Field) 800 bopd & 0.4 mmscfd (PPR for a plateau period of two (2) years followed by declining profiles).



Figure 2.1: Project Location from the nearest cities



a Figure 2.2: Proposed Project Location and other AWEL blocks



2.2 PROJECT LOCATION

Details of Blocks

Block boundary co-ordinates of various fields is tabulated below in Table 2.3.

Table 2.3: Block Boundary Co-ordinates

Sl. No Field Points Latitude Longitude

1. B-9

A 20°10’53.88” N 71°22’44.13” E B 20°04’20.03” N 71°29’43.40” E C 20°00’29.86” N 71°28’49.56” E D 20°00’23.72” N 71°26’04.36” E E 20°06’44.21” N 71°25’01.02” E F 20°06’32.26” N 71°20’13.92” E G 20°08’56.76” N 71°18’52.32” E

2. B-7

A 19°59’29.60” N 71°07’29.00” E B 19°59’36.37” N 71°09’13.69” E C 19°59’27.67” N 71°11’48.86” E D 19°58’18.92” N 71°12’00.32” E E 19°57’31.03” N 71°07’47.36” E

3. BRC

A 19°53’59.72” N 71°09’58.11” E B 19°54’00.32” N 71°12’59.65” E C 19°51’32.77” N 71°12’59.10” E D 19°52’11.67” N 71°09’38.40” E

Details of Well head Platforms

The Coordinates of Well-Head platform are given below in Table 2.4.

Table 2.4 Well-Head Coordinates

S. No. Field Latitude Longitude Remarks B-9 Field Well Co-ordinates

1. Well-Head Platform 1 (B-9-1 area) 20°08'19.09"N 71°21'59.92"E

Surface location of 4 wells

2. Well-Head Platform 2 (B-9-3 area) 20°05’39.63"N 71°26’0.92" E

Surface location of 3 wells

B-7 Field Well Co-ordinates 3.

Well-Head Platform 3 19°58’45.33" N 71°08'39.4" E Surface location of 3 wells in B-7

BRC Field Well Co-ordinates 4. Well-Head Platform 4 19°53’05.911”N 71°10'51.267" E Surface location

of 2 well in BRC



2.3 PROJECT DESCRIPTION

Drilling operations shall be carried out at B-9 clusters offshore fields to extract the trapped hydrocarbons. The gas produced from the wells will be co-mingled and sent to ONGC’s C-24 RP platform located nearly 80 km from the project site via 80 km sub sea pipelines. The processing of the oil and gas is envisaged to be done by ONGC facilities. No onshore facilities are envisaged in the current concept.

The platforms are planned to be minimum facilities well-head platforms comprising of well-head, production & test manifold, well-head control panel, scrapper launcher, instrument gas system, local power generation (solar or other), heli-deck, jib-crane, fiscal metering, real-time production data transfer to Director General of Hydrocarbon (DGH) through satellite communication, etc.

On-bottom stability analysis study will be performed at the design stage and appropriate requirements for protection of pipeline, environment & other consideration like security will be finalised during the design phase.

The development for B-7 field & BRC field will include installation of 2 well-head platforms, inter-field sub-sea pipelines and hooking up at B-9 area. The BRC platform is also envisaged to include facilities to handle, stabilise, store and export oil.

The conceptual sub-sea pipeline layout plan for B-9 DSF Cluster Fields development is shown in Figure 2.3.

Figure 2.3: Conceptual Sub-Sea Pipeline Layout Plan for B-9 DSF 2.3.1 Details of Proposed Pipelines

The proposed development project also comprises of :

• Laying of approx. 80 km sub-sea pipeline (upto 10”) from B9 field to a nearby ONGC platform and hooking-up with the platform facilities.



• Laying of approx. 10 km intra-field sub-sea pipeline (upto 8”) within the B-9 area and hooking-up with the platform facilities.

• Laying of approx. 30 km sub-sea pipeline (upto 8”) from B-7 platform/ area to B9 platforms/area and hooking-up with the platform facilities.

• Laying of approx. 10 km sub-sea pipeline (upto 6”) from BRC platform/ area to B-7 platform /area or B-9 platforms/ area and hooking-up with the platform facilities. The details are to be finalised during the design phase of the development. (Table 2.5)

Table 2.5 Pipelines Specification

S. No.

Length of Sub Sea Pipelines

Size From To Remarks

1. 80 km 10” B9 ONGC To be hooked-up with the nearby ONGC platform.

2. 10 km 8” B9 Within B9 block

Hooking up witthin B9 platform facilities.

3. 30 km 8” B7 B9 To be hooked-up from B7 to B9 platform and facilities.

4. 10 km 6” BRC B7 To be hooked-up from BRC platform to B7 platform facilities.

The project is planned to be executed through a EPIC (Engineering, Procurement, Installation & Commissioning) Contract and the Contractor would perform detailed design, procure, fabricate/construct platforms & jackets, install platforms, jackets & pipeline, hook-up and commission. Platform jackets being considered as mono-towers or three-legged jackets or alternatives. The platforms & jackets will be fabricated at a remote fabrication yards (in India or abroad), transported to the offshore field through barges, installed and commissioned. The pipelines will be sourced from reputed mills, corrosion/weight coated, transported to the field through barges/vessels, installed sub-sea, hooked up with the platforms and commissioned. The basic field parameters are mentioned in Table 2.6.

Table 2.6: Field Paramters

Field Parameters B-9 B-7 BRC

Area (sq. km) 138.5 22.7 22.03 Water Depth (m) 32 - - Hydrocarbon Natural Gas Natural Gas Oil Development Wells Seven (7) Three (3) Two (2)

The fields are proposed to be operated unmanned with periodical visits through helicopter/ boat-landing to conduct routine maintenance, well interventions and any related repair work. The estimated life of the field is nearly 10 years. At the end of the project lifecycle, the offshore platform facilities will be decommissioned according to the standard oil field practices.



2.3.2 Gas and Oil Processing

Processing of the oil and gas is envisaged to be done at existing third party facilities. Gas will be further routed by the third party to their existing on-shore gas processing complex from where the gas buyers’ off take point will be identified later. No onshore facilities are currently envisaged in the project.

2.3.3 Overall Indicative Production Profile for B-9 Field

The profile of overall production for B9 field is shown below in Table 2.7.

Table 2.7- Production Profile of B-9 Field. Date (dd-mm-yyyy)

B-9 Profile B-7 Profile Gas Rate

(MMscf/day) Cum Gas Produced

Bscf

Number of Producers

Gas Rate (MMscf/day)

Cum Gas Produced

Bscf

Number of Producers

4/1/2019 15.0 0.0 3.0 4/1/2020 32.0 11.7 7.0 4/1/2021 32.0 23.4 7.0 21.0 7.7 3.0 4/1/2022 32.0 35.1 7.0 21.0 15.3 3.0 4/1/2023 25.4 46.1 7.0 21.0 23.0 3.0 4/1/2024 16.6 53.7 7.0 21.0 30.7 3.0 4/1/2025 10.5 58.6 7.0 13.6 35.6 3.0 4/1/2026 6.5 61.7 7.0 8.8 38.9 3.0 4/1/2027 3.9 63.6 7.0 5.7 41.0 3.0 4/1/2028 1.8 64.4 7.0 3.7 42.3 3.0 4/1/2029 1.2 64.9 7.0 2.4 43.2 3.0 4/1/2030 1.6 43.8 3.0

Production potential from the BRC field is being evaluated. Profiles will be estimated after detailed G & G evaluation.

Drilling Phase Activities:

Upon the completion of the drilling preparation, the drilling rig and associated equipment will be moved onto the location. Drilling of the wells shall be conducted by Jack-Up Rig, which is the most popular type of mobile offshore drilling unit (MODU) for offshore exploration and development purposes. The drilling rigs and the spread includes supply vessels which will primarily run on diesel and power that will be generated within the rigs/vessels through diesel generators (DG sets). Maximum capacity of cranes is expected to be 100 Tons. Wells are tentatively planned to be drilled with 4 casing policy having 30” Conductor, 20” Surface Casing, 13-3/8” & 9 5/8” Intermediate Casings and 7’ Production Liners. Completion strings will be 3 ½” Tubings with gas-tight connections. Wells are planned to be completed with sand-screens. The rig will either be transported to location by outside vessel such as tug/barge or has their own propulsion method for transport. A typical Jack-Up Rig is shown in Photo Plate 2.1.



Photo Plate 2.1: A Typical Jack-Up Rig

General Platform Facilities Description:

The well-heads planned are integrated wellhead-4CP 10K type with matching Christmas-trees. The well-head facility will consist of production & test manifold, pig launching and receiving facility for pipeline and receiving facility for well fluid, closed drain & open drain system and cold vent system. The main function of the well-head is to maintain surface control of the well. The electrical power for the platform is generated by means of Solar Power System and distributed through power distribution boards and for deck crane, power is generated by diesel engine generator system. Further, the platform shall have instrument & utility gas system, corrosion inhibitor injection system, material handling and safety equipment. Each well online monitoring to be performed by using orifice meter. Well testing to be performed by using multi phase flow meter. The well testing will be a manned operation. Platform facilities are mentioned in Table 2.8.

Table 2.8: Details of Platform Facilities

Fields

Parameters

B-9 (7 Wells)

(2 Platforms)

B-7 (3 Wells)

(1 Platform)

BRC (2 Wells)

(1 Platform) Orifice Flow Meter One per well One per well One per well

Multiphase Flow Meter One per Platform One per Platform One per Platform

Production Manifold Test Manifold Comingling Manifold

Available Available

Available (B9-1)

Available Available

Available Available

High Integrity Pressure protection System

Available Available Available

Pig Launcher Pig Receiver


Cold vent System Available Available Available Closed and Open Drain System


Diesel System Available Available Available



Fields

Parameters

B-9 (7 Wells)

(2 Platforms)

B-7 (3 Wells)

(1 Platform)

BRC (2 Wells)

(1 Platform) Chemical Injection System Available Available Available Instrument and Utility Gas System: Fire & gas Detection System Remote Telemetry Unit


Potable Water System (Wash Water System for Deck & Toilet)


Material Handling Facilities Available Available Available Safety and Evacuation Items


Solar Power System Available Available Available Navigational Aid System Available Available Available Cathodic Protection System Available Available Available

2.3.4 Electrical Systems

The electrical system is designed to provide:

a. Safety to personnel and equipment b. Reliability of service c. Minimal fire risk d. Operational flexibility e. Optimization of available space f. Ease of maintenance and convenience of operation

The environment and site conditions on the platform will be extremely saline, humid, corrosive and hostile marine environment. All the electrical equipment, systems, apparatus and material for installation on the platform to be suitable for operation service under this extreme environment conditions. In general, all outdoor electrical equipment, systems and apparatus to be designed for 40°C temperature and relative humidity of 100% while the indoor equipment, systems and apparatus to be designed for 45°C temperature and relative humidity of 100%.

The design life for all the platform electrical equipment to be minimum 10 years except for the cathodic protections system whose design life to be same as jacket design life (minimum of 15 years).

2.3.5 Telecommunication System

To facilitate the platform for Voice, Data & Security Surveillance, a telecommunication system is proposed as given below:

a. VSAT SYSTEM- (Voice and Data communication) b. CCTV SYSTEM- (Security Surveillance)



Communication System shall be designed in such a way that the required data from the Well-head platform is transmitted to the cloud server at Directorate General of Hydrocarbon (DGH) and AWEL Facility.

2.3.5.1 VSAT system

VSAT system to be the primary Communication for Voice & Data. VSAT Telecom Facilitator/operator will be fully responsible for delivering the data collected from all proposed platforms and C24-RP (existing platform) to AWEL Facility and DGH. VSAT system shall also be considered for voice communication between/within B-9-1, B-9-3, B-7 and BRC well-head platforms for voice through Walkie-Talkie.

2.3.5.2 CCTV System CCTV security camera to be provided at all unmanned platforms for the security surveillance. The images from the camera to be routed through VSAT to AWEL facility with governance of VSAT telecom facilitator/operator.

2.3.6 Softwares

The SACS software developed and marketed by Bentley, to be the primary structural analysis tool for the jacket and topsides design. Release 5.7 version to be used. The software comprises several compatible structural analysis modules that can perform the following:

a. Interactive full screen modelling and editing

b. Generation of environmental loads

c. Non-linear soil, pile and structure interaction

d. Static analysis and code checking

e. Dynamic analysis

f. Deterministic fatigue analysis

g. Flotation and Upending analysis

2.3.7 Supply Base

The supply base is very important for the successful completion of drilling programme. The Company’s supply base is available at Pipavav. The main advantage of this is its proximity to operational area. Offshore Support Vessels (OSV’s) can reach the location in less than 10 Hrs.



2.3.8 Staffing

The remote Well-head Platforms are to be automated for unmanned operation, with personal presence required for routine checks, replenishing consumables (diesel, utility water, chemical etc.), maintenance, and restart following an emergency shut-down. Sufficient operating data is to be communicated to onshore station to monitor the status of safety and production of critical systems.

2.4 RESOURCE UTILIZATION

2.4.1 Water Requirement

It has been estimated that 45-55 kilo litres per day (KLD) of water for each well shall be required during drilling and installation activities. The water requirements for domestic use shall be met from the sea water, which shall be treated prior to its use. Potable water to be supplied through tanks.

2.4.2 Power Requirement

Diesel to be supplied from boat to diesel storage tank at platform. It has been estimated that 8-12 KLD of high speed diesel shall be required for running captive gensets of drilling rigs, deck crane operation, and offshore vessels. The solar power system is the only source of electrical power to feed the entire platform loads without any alternate power sources. Electrical loads and sizing of the solar power system to be determined based on the requirement of the navigational aids system loads, lighting loads and all Instrumentation & Telecommunication loads. Components of power supply system to be of highest available quality for reliability and long service life. Power supplies for all transmitters, controllers, signal converters, electric system and components in shutdown system to be supplied from uninterruptible power supplies. Power distribution to each consumer to be through proper, independent switch and fuse. Protective fuses to be of indicating cartridge type mounted in fuse holders.

The power generated from the solar power system feeds various basic platform loads and charges the battery in normal conditions, i.e. during the day time and the energy stored in battery feeds the loads under during night or ‘NO-SUN’ conditions for minimum 7 days.

There are four (4) separate/individual solar power systems for feeding the below listed system loads which are categorised based on the criticality of the loads with output voltage level of 24V DC ±10%.

SYSTEM-I : Solar Power System for Navigational Aids System SYSTEM-II : Solar Power System for Lighting & Instrumentation System SYSTEM-III : Solar Power System for Remote Telemetry Unit (RTU) System SYSTEM-IV : Solar Power System for Fire & Gas Detection System

In general, the following power supplies to be used for instrumentation and control: 24V DC +5% / -10%, with Floating Earth / Unearthed except for RTU which is Negative Earthed System.



2.5 NOISE, AIR EMISSIONS, EFFLUENTS, AND SOLID WASTE GENERATION

2.5.1 Noise

Noise is likely to be generated mainly due to operation of generator sets and pumps during the project activities. Noise may also be generated due to movement of transportation vessels during the project activities.

2.5.2 Emissions

Air pollution will be from burning of fuel in the generator sets required for power generation during the project activities. The proposed drilling operations will require a number of generator sets, to cater to the power requirement. However, these will be placed near to eachother & hence their emissions, for all practical purposes, can be considered to be from a single group source, instead of various point sources. Air emissions may result from gas flaring activities during the well testing (four days per well).

2.5.3 Effluents and Solid Waste

The following types of wastes are likely to be generated during the project activities:

a. Drill Cuttings (DC) : The drill cuttings will be generated during drilling phase of wells. Cuttings free from Water Based Mud (WBM) will be discharged offshore into sea as per G.S.R. 546 (E), dated 30/08/2005, according to which the cuttings will be discharged to sea intermittently, at an average rate of 50 bbl/hr/well from a platform so as to have proper dilution and dispersion without any adverse impact on marine environment whereas cuttings generated from Synthetic Oil Based Mud (SOBM) will be brought back to on-shore for treatment and disposal in an impervious waste disposal pit.

b. Produced Water : The management of produced water is very crucial. Safe water management practices and disposal of produced water are vital in protecting the surface and ground water resources. The produced water, if any, separated during hydrocarbon processing will be treated and disposed as per CPCB/MoEF standards.

c. Water-Based Drilling Mud (WBM): WBM will be generated during drilling activities. Only WBM will be used during drilling operations. In case of any problem related to geological formation, Synthetic Oil Based Mud (SOBM) a low toxicity oil based mud will be used and it will be intimated to MoEF/SPCB. SOBM are designed to mirror oil-based mud performance, without the environmental hazards. The range of chemical agents added to achieve specific properties is much reduced compared to water based mud systems. It typically consists of base oil, primary and secondary emulsifier, viscosifier, barite, lime, water and other components depended on the condition of drilling. As per G.S.R. 546 (E), dated 30/08/2005, low toxicity oil based mud of aromatic content < 1% will be used. The toxicity of the chemical additive used in WBM or SOBM will be biodegradable and will have toxicity of 96 hr LC50 value > 30,000 mg/L as per mysid toxicity or toxicity test conducted on locally available sensitive sea species. WBM/SOBM will be recycled to the maximum extent. Thoroughly washed drill cuttings separated from WBM and unusable portion of WBM (toxicity of 96 hr LC50 Value > 30,000 mg/L) will be discharged offshore into sea intermittently, at an average rate of 50 bbl/hr/well from a platform so as to have proper dilution and dispersion without any adverse impact on marine environment whereas unusable portion and drill cuttings generated from SOBM (toxicity of 96 hr LC50 Value > 30,000 mg/L) will be



brought back to on-shore for treatment and subsequent disposal in an impervious waste disposal pit.

d. Hazardous Waste: Hazardous waste such as waste lube/system oil from machinery, used oil from generator sets (in case of operation) are likely to be generated. The waste shall be handled as per Hazardous Wastes (Management, Handling and Trans-boundary Movement) Rules, 2008. The hazardous area classification to be carried out in accordance with the API. Hazardous areas to be classified as Zone 0, Zone 1 and Zone 2 according to degree of hazard in accordance with API RP 505. This code allows the use of equipment designed and certified to IEC and NEC Article 505 Standards. Generally, the hazardous area classification drawing to be the basis of selection of electrical equipment for various locations.

The waste will be carefully stored in drums and transported to MoEF approved recyclers for its final disposal.

2.5.4 HSE Requirement

The Facilities shall be designed and constructed as per standard existing oilfield practices, and are to be operated and maintained to meet the safety philosophies and criteria outlined hereunder. Key elements in achieving the safety objectives are:

a. The facilities shall be designed, constructed, and are to be operated and maintained such that they are fail-safe and of high safety integrity.

b. The selected process configuration and equipment shall have proven safety and operability characteristics.

c. The Facilities engineering design processes shall include thorough quantitative and qualitative safety case assessments and safety reviews, including the HAZOP process etc.

d. The Facilities shall be constructed, installed and are to be operated and maintained in accordance with safe work practices and procedures. The target site safety objective shall be zero lost time injury (LTI) frequency rate.

e. Site emergency response and evacuation procedures shall be developed and personnel will be trained /instructed in these procedural requirements.

f. All statutory compliance such as Environmental Clearance (EC), approvals from OISD, State Maritime board, Defence / MHA/ MoD Clearances etc. shall be strictly enforced.

g. Safety studies such as HAZID, HAZOP, SIL Safety case, material handling, etc. would to be conducted and all action items closed. All documentation shall be properly maintained and made available to Authorities for verification.

h. The wells shall be drilled as per API & OISD standards. Drilling equipment and services shall be selected as per the above Guidelines.

All well related safety devices such as Blow-out Preventers (BOP), Safety valves, etc. shall be tested as per API, OISD or other Statutory Guidelines and records kept.

33

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3. DESCRIPTION OF THE ENVIRONMENT

3.1 INTRODUCTION

This chapter presents an overview of the existing environmental aspects related to the development of B-9 cluster offshore fields in the discovered small fields (DSF) in the Mumbai Offshore Basin. The assessment of the characteristics of local biological environment allows an understanding of the potential impacts on the marine environment, thereby adopting relevant control measures to mitigate the adverse negative impacts.

The state of the environment has been characterized on various marine components in the project site and its surrounding areas. The project site comprises of 3 DSF, i.e., B-9, B-7 and BRC blocks in the Mumbai offshore basin, wherein B-9 and B-7 are Gas fields and BRC is an Oil field. The study area pertains to 15 km radial distance from each of the three (3) DSFs and proposed pipelines. The project location with demarcated oil and gas (O&G) field blocks is depicted in the Figure 3.1 below.

The offshore O&G exploration, development and production activities are covered under Schedule 1(b) of the EIA notification, 2006 and being a ‘Category A’ project it was appraised at Central level by the Sectoral Expert Appraisal Committee (EAC) in MoEF&CC.

3



Figure 3.1: Project Location



3.2 ENVIRONMENTAL BASELINE

The project site is an oceanic study area located in the Arabian Sea approximately 177 km from Mumbai and 72 km from Diu Coast. The nearest land parcel to the block falls between Diu and Bhavnagar section on the Saurashtra coast. The baseline description includes collection of primary and secondary data on relevant environmental characteristics through field survey, environmental monitoring, and secondary sources viz. maps, reports, scientific literatures etc. The collated data was analyzed to identify the impacts of the project activities, thereby adopting relevant mitigation interventions for minimizing its adverse effect. The activities that are likely to be studied for each environmental component are described in the subsequent sections. The environment status of the project area was studied during Pre-Monsoon season starting March 2018 to May 2018 which is further elaborated in the sub sections below.

Scope of Work

The scope of work for establishing environmental baseline includes:

• Collection of water samples for monitoring hydrographical chemical and biological characteristics including contaminants like hydrocarbons and heavy metals.

• Collection of sediment samples for quantifying various components including hydrocarbon deposition, heavy metal concentrations and benthic biota.

3.3 APPLICABILITY OF COASTAL REGULATION ZONE (CRZ):

Since the project area is located beyond 12 nautical miles (NM) from the coast line, the Coastal Regulation Zone (CRZ) Regulations 2011, therefore, is not applicable. The map depicting the project site and its distance from nearest cities is given in Figure 3.2.



Figure 3.2: Nearest cities to the Project Location



3.4 GEOLOGY OF MUMBAI OFFSHORE BASIN

Mumbai Offshore basin is located on the western continental shelf of India between Saurashtra basin in NNW and Kerala Konkan in the south.

Type of Basin

Mumbai offshore is a pericratonic rift basin situated on western continental margin of India. Towards NNE it continues into the inland Cambay basin. It is bounded in the northwest by Saurashtra peninsula, north by Diu Arch. Its southern limit is marked by east west trending Vengurla Arch to the South of Ratnagiri and to the east by Indian craton.

Different Tectonic Zones within the Basin

Five distinct structural provinces with different tectonic and stratigraphic events can be identified within the basin viz. Surat Depression (Tapti-Daman Block) in the north, Panna-Bassein-Heera Block in the east central part, Ratnagiri in the southern part, Mumbai High-/ Platform-Deep Continental Shelf (DCS) in the mid-western side and Shelf Margin adjoing DCS and the Ratnagiri Shelf.1

Reservoir Rock

Mumbai offshore basin has been blessed with both clastic and carbonate reservoir facies in almost total Tertiary Section ranging from Paleocene to Middle Miocene (Table 3.1).

Table 3.1: Reservoir Rock in the Mumbai Offshore Basin

Reservoir

Sl. No. Age Lithology/ Location 1. Middle Miocene Carbonate sections at Ratnagiri, Mumbai high & Diu

(Ratnagiri & Bandra formations) 2. Lower Miocene Represented by a thick pile of carbonates hosting huge

quantity of oil and gas over Mumbai High (Bombay, Ratnagiri)

3. Oligo– Early Miocene

Sands in the central and mid-eastern part of Surat depression i.e. Tapti- Daman area, Daman formation. Carbonates adjoining Mumbai High( Panvel formation )

4. Eocene and Early Oligocene

E.Oligocene clastics of Surat depression (Mahuva Formation) Deposition of thicker carbonate facies over the horst blocks in Panna- Basein-Heera and Ratnagiri blocks (Bassein, Mukta & Heera formations).

5. Paleocene Coarser clastic facies developed within the upper marine shale sequence in areas of Mumbai High, Panna and Ratnagiri (Panna Formation).

1 https://www.ndrdgh.gov.in

https://www.ndrdgh.gov.in/NDR/Images/MumbaiOffshore/MumbaiOffshore.jpg

https://www.ndrdgh.gov.in/NDR/Images/MumbaiOffshore/TectonicMumbai.jpg

https://www.ndrdgh.gov.in/



3.5 CLIMATE AND METEOROLOGY

Mumbai Offshore Basin has a tropical wet and dry climate under the Koppen climate classification2. The area/region does not experience distinct seasons, but the climate can broadly be classified into two main seasons—the humid season and the dry season. Usually, the period between October to May is relatively dry. The region gets southwest monsoon rains beginning June to end September with peak rains occurring in July. Occasionally, northeast monsoon showers occur in October and November.

The project area is in the Arabian Sea off the Northwest coast of India. The Arabian Sea that forms the part of the Indian Ocean north of the equator is separated from the deep reaching vertical convection areas of the northern hemisphere, by the Asian continent. Such an asymmetric configuration leads to a weak circulation and poor renewal at depths in the Arabian Sea.

3.5.1 Mean Sea Surface Temperature

According to the National Oceanic and Atmospheric Administration (NOAA), the maximum and minimum value of mean sea surface temperature in the Arabian Sea is of the order of 30.8ºC and 26.04 ºC, respectively. Figure 3.3.

Figure 3.3: Sea Surface Temperature

2 City Profile of Greater Mumbai, 2011.



3.5.2 Mean Air Temperature

As per available data with Physical Sciences Division, Earth System Research Laboratory, NOAA, Boulder, Colorado,maximum and minimum value of mean air temperature in the Arabian Sea is of the order of 30.2ºC and 24.04 ºC, respectively.

3.5.3 Mean Wind Speed

The study of average hourly wind speed in project area shows significant seasonal variation over the course of the year. The windier part of the year lasts for 2.9 months, from June 1st to August 30th, with average wind speeds of more than 10.6 miles per hour. Figure 3.4, shows the variation in wind speed along with wind direction around the proposed project location.

Figure 3.4: Wind Speed and Wind Direction



The dispersion of pollutants is influenced by the wind speed and wind direction for an area. It is considered as the important data for predicting the air quality impacts.

The prominent wind directions at the project area is from Northwest (44%). The highest wind speed observed from northwest direction was more than or equal to 11.10 m/s. There was no calm wind condition during the study period i.e., February to May. Pattern of Wind direction in the project area is presented in Figure 3.5.

Figure 3.5: Wind Rose for the Months of February to May 2018

3.5.4 Waves and Tides

As per available data with Physical Sciences Division, Earth System Research Laboratory, NOAA, Boulder, Colorado, Predominant significant wave height and zero-crossing period are 50 to 70 cm and 8 to 8.5 sec respectively. The predominant wave periods and wave heights are 5-6 sec and 0.5 to 1.5 m respectively during the fair-weather season (October-May) and 5-9 sec and 1-3 m respectively during the rough weather season (June-September). A wide range of wave heights 0.5-5 m occurs during the rough season.

The tides in the offshore area are of mixed semi-diurnal type with a large diurnal inequality. The gulf water behave as homogeneous one-layered structure due to high tidal range, low run-off from land, shallow depth, and irregular bottom topography – all suitable for turbulent flow



field. Unpredictable rip currents may show up due to the difference in shelf / depth together with weather pattern.

3.5.5 Rainfall

The area is within the monsoon belt, experiencing south westerly, rain bearing winds from June to September followed by dry wind spell from October to May. The land segment nearest to the block falls between Diu and Bhavnagar section on the Saurashtra coast. The climate is semi-arid with an average rainfall of 500 to 600 mm.

3.5.6 Cyclones

The west coast is less prone to depressions and cyclones as compared to the east coast of India. The frequency of cyclonic disturbances varies significantly with the season. Generally, cyclonic conditions prevail during May-June and become more frequent in July-November while, the weather is relatively tranquil during February-March (Figure 3.6).

Figure 3.6: Cyclone Prone Area



3.5.7 Circulation

Circulation in the gulf is mainly controlled by tidal flows and bathymetry. Strong currents normally occur during mid-tide, i.e. 2-3 hrs. before and after low and high tides. The spring currents are 60-65% stronger than the neap currents. The surface currents are moderate (0.7 to 1.2 m/s) but increases considerably (2.0-2.5 m/s) in the central portion of the gulf. The bottom currents are periodically strong with bimodal directions generally parallel to the uneven bottom contour. The associated tidal currents are fairly strong and bimodal in nature having two dominant directions – upstream during flood and downstream during ebb in all-encompassing oscillatory motions. The circulation pattern in the near shore areas however is modified considerably due to the presence of creeks and inlets.

3.6 MARINE ENVIRONMENT

Water and sediment quality sampling was carried out in B-9, B-7and BRC blocks of the cluster offshore fields in the Mumbai Offshore Basin. The samples collected were further considered for laboratory analysis.

3.6.1 Sampling Methodology

A survey vessel scrutinized by Offshore Défense Advisory Group (ODAG) was hired for offshore sampling. The vessel was well-equipped with Global Positioning System (GPS) and Radar for accurate positioning, radio communication and satellite telephone for communication. The survey vessel was cruised to the sampling locations according to the given geographical coordinates, i.e., latitude and longitude of the sampling locations. The water and sediment samples were drawn from 2 levels in the sea, i.e., at the surface and bottom levels for each of the five (5) sampling locations. The documents for Vessel, ODAG clearance, Inspection pictures and details of GPS Data Log are annexed as Annexure- III to VII.

3.6.1.1 Sea Water Sampling

The sea water (SW) samples were collected from two (2) levels in the sea using a Niskin Sampler of 5 litres capacity. The depth levels are as follows:

a. Sample 1 – 3 m below the surface b. Sample 2 - Few meters above the sea bed

Analysis Method:

The water samples were analyzed by the following methods suggested by Grasshoff (1983) and APHA (1985). All the colorimetric estimations were done using double beam spectrophotometer (Genesys 10 UV Thermo Spectronic). pH was measured using a pH meter MK-Vl. The sampling depth specifications and coordinates of sampling locations are tabulated in Table 3.2 below. The quantity of SW collected along with the techniques for the preservation of the samples are depicted in Table 3.3.

Figure 3.7 and Figure 3.8 below highlights the five (5) water sampling locations along with the route followed by the survey vessel in the Mumbai Offshore Basin during environmental sampling and sampling location map at the project site within the study area. A typical Niskin sampler is depicted in Figure 3.9.



Table 3.2: Specifications of Sea Water (SW) Sampling Location

S. No.

Sampling Location

Location Code

Latitude (N)

Longitude (E)

Sea Water Sampling Depth Bottom (m) Surface (m)

1. B9-1 SW1 20° 08’.23.0” 71°21’.42.7” 33 3 2. B9-2 SW2 20° 05’.37.8” 71°26’.23.6” 33 3 3. B9-3 SW3 20° 01’.48.1” 71°27’.34.4” 34 3 4. B7 SW4 19° 58’.34.4” 71°11’.37.1” 42 3 5. BRC SW5 19° 53’.36.4” 71°10’.54.2” 39 3

Table 3.3: Preservation of Water Samples

S. No. Sample Particulars Sample Quantity Preservation

1.

Dissolved Oxygen 300 ml in glass stoppered bottle/ BOD Bottle

2 ml Wrinkler’s A (Manganous Sulfate) followed by 2 ml Wrinkler’s B (Alkaline Iodide Sodium Azide Solution)

Oil and Grease 1 Litre in wide mouth glass bottle

Adjust pH to <2 with conc. Sulfuric Acid or Hydrochloric Acid

Metals 1 Litre in PP container Adjust pH to <2 with conc. Nitric Acid

Other Physio-chemical Parameters

2 Litre in PP/PE container Refrigerate at 4°C

2.

Primary productivity

300 ml in glass stoppered bottle/ BOD Bottle

• Fixed immediately after sampling as described for Dissolved Oxygen preservation

• Keep in dark or wrapped in Aluminum wrapper and then refrigerate

Chlorophyll 1 Litre sample in wide mount PP Bottle

----------------------------

Phytoplankton 1 Litre water sample filtered through plankton net

Preserved with Lugol’s Iodine immediately and stored in dark

Zooplanktons 1 Litre water sample filtered through plankton net

Preserved with Formalin immediately



Figure 3.7: Sea Water Sampling Locations with Vessel Route

(ONGC Platform)



Figure 3.8: Sea Water Sampling Locations within Study Area



Figure 3.9: A Typical NISKIN Sampler

Photo Plate 3.1 shows the water sample collection activities at various sampling locations during field data collection.

Marine Water Sampling using NISKIN Sampler

On-Site Preservation of Samples



Sample Storage for Lab Analysis Marine Water Sampling using NISKIN Sampler

Photo Plate 3.1: Marine Water Sampling

The results of the marine water quality analysis are tabulated in Table 3.4.



Table 3.4: Marine Water Quality Analysis*

S. No. Parameters Unit DL

SW1 at B9-1 SW2 at B9-2 SW3 at B9-3 SW4 at B7 SW5 at BRC

Surface Bottom Surface Bottom Surface Bottom Surface Bottom Surface Bottom

1. pH -- -- 8.1 8.0 8.1 8.1 8.2 8.2 8.2 8.2 8.2 8.2

2. Electrical Conductivity mS/cm -- 47760 46540 45240 44930 45370 45540 44930 44380 45190 44980

3. Dissolved Oxygen mg/L -- 5.2 5 4.8 4.6 4.9 4.5 4.6 4.4 4.8 4.6 4. Salinity Ppt -- 35.3 35.1 32.8 36.1 35.3 34.6 35.6 36.1 35.9 36.9 5. Total Dissolved Solids mg/L -- 31856 31744 30244 32158 31622 30122 33258 34692 33568 35482

6. Total Suspended Solids mg/L -- 77 86 45 93 77 70 91 91 63 86

7. Total Hardness as CaCO₃ mg/L -- 8000 10000 8000 10000 10000 8000 8400 9000 8600 8000

8. BOD (@ 27°C, 3 Days) mg/L 2 BDL BDL BDL BDL BDL BDL BDL BDL BDL BDL

9. Total Alkalinity as CaCO₃ mg/L -- 126 130 130 126 130 132 130 130 130 128

10. Nitrates as NO³- mg/L 0.44 0.88 0.78 0.64 BDL 0.68 BDL BDL BDL BDL BDL 11. Sulphate as SO₄2- mg/L -- 3520 3570 3298 3454 2444 2474 2514 3536 3312 2590 12. Oil & Grease mg/L 10 BDL BDL BDL BDL BDL BDL BDL BDL BDL BDL 13. Chlorides as Cl mg/L -- 19563 19420 18135 19991 19563 19134 19706 19991 19848 20419

14. Residual Free Chlorine mg/L 0.1 BDL BDL BDL BDL BDL BDL BDL BDL BDL BDL

15. Iron as Fe mg/L 0.06 BDL BDL BDL BDL BDL BDL 0.41 BDL 3.1 0.9 16. Manganese as Mn mg/L 0.03 BDL BDL BDL BDL 0.05 BDL BDL 0.09 BDL 0.07 17. Cadmium as Cd mg/L 0.015 BDL BDL BDL BDL BDL BDL 0.015 0.015 BDL BDL 18. Chromium as Cr⁶+ mg/L 0.01 BDL BDL BDL BDL BDL BDL BDL BDL BDL BDL



S. No. Parameters Unit DL

SW1 at B9-1 SW2 at B9-2 SW3 at B9-3 SW4 at B7 SW5 at BRC

Surface Bottom Surface Bottom Surface Bottom Surface Bottom Surface Bottom

19. Lead as Pb mg/L 0.01 BDL BDL BDL BDL BDL BDL 0.02 0.01 BDL BDL 20. Nickel as Ni mg/L 0.02 BDL BDL BDL BDL BDL BDL 0.02 BDL BDL BDL 21. Zinc as Zn mg/L 0.02 BDL BDL BDL BDL 0.3 0.05 BDL 0.02 0.02 0.02 22. Mercury as Hg mg/L 0.0015 BDL BDL 0.0015 BDL 0.0027 BDL 0.0023 0.0016 BDL 0.0015 23. Arsenic as As mg/L 0.03 BDL BDL BDL BDL BDL BDL BDL BDL BDL BDL

*Note:

1. DL – Detection Limit 2. BDL – Below Detection Limit



All the five samples (surface and bottom) from the 3 designated O&G fields in the project location were collected during the study period i.e. May 2018.

Results of Sea Water Monitoring

The observed pH value in the study region during the period of study is in the range of 8.0 to 8.2.The changes in pH are marginal as expected for natural marine waters sustaining low primary productivity. The total hardness (as CaCO₃) in all the water sample lies in the range of 8000 to 10000 mg/L. The value of alkalinity (as CaCO₃) was in the range of 126 to 132 mg/l. The dissolved oxygen ranges from 4.4 mg/l to 5.2 mg/l.

The concentrations of Chloride in all the sample were in the range of 18135 to 20419 mg/L. The contents of oil & grease in all sample was below detectable limit (BDL) in all the sampling locations.

The BOD levels in all water samples was found to be below detection limit (BDL) wherein the detection limit for BOD is 2 mg/L.

It has been observed from the laboratory analysis that residual free chlorine, Cr⁶+, and as were below detection limits in all the water samples. Whereas, there has been observed a slight detection in few samples in regard to the concentration of lead, nickel, zinc and mercury.

3.6.1.2 Sea Sediments Sampling

Marine sediments play a very important role as repositories of organic matter and nutrients for the ecosystem but at the same time, they are vulnerable to heavy metal and organic toxics (from anthropogenic activities) especially in the offshore oil and gas.

Five (5) sea sediment (SS) samples were collected from the project site, Mumbai Offshore Basin as depicted in the Figure 3.10 and Figure 3.11 below.

Sea sediment samples were collected using a Van-Veen Grab Sampler. It is an instrument to sample sediment in water environments (Figure 3.12). The grab was lowered vertically from the stationary boat until it touched the bottom. Sediment samples were collected and preserved for sediment texture analysis and physico-chemical analysis. The SS sampling location coordinates along with the sampling depth are tabulated in Table 3.5. The quantity of SS collected along with the techniques for the preservation of the samples are depicted in Table 3.6.



Figure 3.10: Sea Sediment (SS) Sampling Location & Vessel Route

(ONGC Platform)



Figure 3.11: Sea Sediment (SS) Sampling Location & Vessel within Study Area



Figure 3.12: Typical Van-Veen Grab Sampler

Table 3.5: Specifications of Sea Sediment (SS) Sampling Location

S. No

Sampling Location

Location Code

Latitude (N)

Longitude (E) Sea Sediment

Sampling Depth (m)

1. B9-1 SS1 20° 08’.23.0” 71°21’.42.7” 40 2. B9-2 SS2 20° 05’.37.8” 71°26’.23.6” 40 3. B9-3 SS3 20° 01’.48.1” 71°27’.34.4” 40 4. B7 SS4 19° 58’.34.4” 71°11’.37.1” 58 5. BRC SS5 19° 53’.36.4” 71°10’.54.2” 54

Table 3.6: Preservation of Sediment Samples

S. No Sample Particulars Sample Quantity Preservation 1. Marine Sediment 1 kg in leakage protective bag Refrigerate at 4°C

2. Marine Benthos Sediment collected from sea bed sieved through 500-micron test sieve stored in 125 ml wide mouth PP bottle

Preserved with Formalin immediately

Photo Plate 3.2 shows the collection of sediment from the various sampling locations.

Photo Plate 3.2: Sediment Sample Collection from Mumbai Offshore Basin



The results of the marine sediment quality analysis are tabulated in Table 3.7 below.

Table 3.7: Offshore Marine Sediment Quality Analysis

S. No. Parameters Unit Detectio

n Limit SS1 at B9-1

SS2 at B9-2

SS3 at B9-3

SS4 at B7

SS5 at BRC

1. pH (1:2.5: Sediment: Water Extract)

-- -- 8.4

8.4

8.2 8.5 8.5

2. Oil and Grease % -- 0.7 0.5

0.4 0.4 0.1

3. Nitrate as Nitrogen mg/kg 2

3

BDL BDL BDL 3

4. Total Kjeldahl Nitrogen mg/kg -- 520

431

440 403 528

5. Hexavalent Chromium as Cr(VI)

mg/kg 0.01 BDL BDL BDL BDL BDL

6. Polyaromatic Hydrocarbon mg/kg -- 0.82 1.12 0.85 0.23 0.61

7. Arsenic as As mg/kg 2 4.2 2.9 BDL BDL 2.3 8. Cadmium as Cd mg/kg 2 BDL BDL BDL BDL BDL 9. Iron as Fe mg/kg 0.44 49318 56797 39243 46442 48497

10. Lead as Pb mg/kg -- 7 6 6 6 5 11. Mercury as As mg/kg 2 BDL BDL 3 BDL BDL 12. Zinc as Zn mg/kg -- 69 65 68 65 60

Results of Sea Sediment Monitoring

Oil and grease ranges from 0.1 to 0.7, Nitrite as Nitrogen found as 3 mg/kg at location SS1& SS5 rest of the location shown the values below detection limits. The Total Kjeldahl Nitrogen ranges from 403 mg/kg to 528 mg/kg.

The hexavalent chromium is found below the detection limit at all the locations.

Among the heavy metals, iron varied from 39,243 mg/kg to 56,797 mg/kg and lead from 5 to 7 mg/kg, zinc showed variation of 60 to 69 mg/kg, cadmium was found below detection limit and arsenic varied from 2.3 mg/kg to 4.2 mg/kg.

Among the exchangeable nutrient fractions of nitrogen, nitrate was found 3 mg/kg at location SS1 & SS5, at rest of the location it is below detection limit i.e. 2. The polyaromatic compounds are found ranges from 0.23 mg/kg to 1.12 mg/kg, the amount of PAH is observed low.

3.6.1.3 Marine Biological Characteristics

Marine environment is known to support vast population of organisms, found distributed in both pelagic and benthic realms. Most of the organisms of the pelagic realm constitute the plankton. Phytoplankton and zooplankton together constitute this community and form the primary food source for most of the marine species. Their response to physio-chemical characteristics of the water column determines their distribution, abundance, and production.3

3 Jeffrey, S.W. and Hallegreff, G.M., 1990. Phytoplankton ecology in Australian waters. In: Clayton, M.N. and King, R.J. (Eds.]. Biology of Marine Plants, Longman — Cheshire, Melbourne. pp: 310-348.



The occurrence of marine species both plants and animals has largely been controlled by the physio-chemical properties of ocean water.

Photo Plate 3.3 shows few glimpses of the ecological sampling done in the B-9 Cluster block, monitoring locations.

Photo Plate 3.3: Ecological Sample Collection from Mumbai Offshore Basin

a) Chlorophyll Analysis

Chlorophyll concentration is the result of the conversion of inorganic nutrients into living biomass and acts as an indicator of the health and productivity of the estuarine ecosystem. However, high levels of chlorophyll for a long duration indicate poor water quality while low levels often suggest good quality. The chlorophyll content around the project location is shown in Figure 3.13.



Figure 3.13: Chlorophyll content in Mumbai Offshore Basin

Methodology

Chlorophyll was estimated following the methods published by UNESCO (1966). A known volume of water sample was filtered through Millipore GF/C filter paper with MgCO3 suspension. Subsequently the filters were extracted with 90% acetone, centrifuged for 10 minutes at 5000 rpm. The extinction of the supernatant solution was measured using spectrophotometer against a reference cell containing 90% acetone at 665, 645 and 630 nm and the concentration was calculated using standard equations.



b) Phytoplankton, Zooplankton and Benthos Analysis

Phytoplankton are the autotrophic organisms and contribute directly to the food available in the surface water by building up their protoplasm and food reserves directly from carbon dioxide. Phytoplankton are very important in food chains in estuarine environment, since 72% of the Earth is covered by ocean. Zooplankton are heterotrophic plankton which thrive on surface waters on phytoplanktonic and other zooplanktonic food reserves. They are very important to the oceanic food cycle. Their distribution is mostly affected by the nutrient availability (lead by water column mixing) and abundance of phytoplankton.

Benthos are organisms dwelling in or above the sediment of water bodies. They play a crucial role in nutrient and carbon cycling either directly or indirectly as deposit feeders, suspension feeders, decomposers, predators, or scavengers and also to the potential and sustainability of demersal or near bottom living resources. However, they are significantly influenced by the trophic changes particularly arising from the anthropogenic factors. Benthos are characterized according to their sizes, namely, micro (<63µm), meio (63 - 500µm) and macro-benthos (>500 µm).

Meiofauna are an important component of benthic habitats due to their small size, abundance and rapid turnover rates and play important roles in benthic food webs. Meiofauna feed on benthic microalgae, other microbes, and detrital food sources and is, in turn, important food resource for grass shrimp and a variety of juvenile fish that utilize shallow water nursery habitats. Through their feeding and burrowing activities, meiofauna help to keep microbial communities active, which serve to enhance productivity and the recycling of nutrient. Meiofauna have been used as environmental indicators of human activities and pollution. Pollutant effects on meiofauna have been shown to depend on pollutant type, the biology of the organisms themselves, exposure levels and environmental setting. The secondary production of meiofauna may equal or exceed that of macrofauna.

Benthic macrofaunal communities have4 been related to substrate type and sometimes designated by the type of bottom sediment they inhabit5. In shelf waters it is now recognized that, within a particular habitat type, biological interactions result in spatial and temporal heterogeneity, even on soft bottoms where 'bioturbation' plays an important role in the structuring and functioning of communities6.

Analysis Methodology

Phytoplankton: Thirty (30) litres of surface water was filtered through phytoplankton net of 20µm mesh size made of bolting silk. The filtrate was preserved in 3% neutralized formaldehyde/Lugol’s iodine solution. Quantitative analysis was done employing Sedgewick-Rafter counting cell. Species identification was done using a Leica DM 2000 LED light microscope.

Enumeration by Sedgewick-Rafter Counting Cell: The planktonic microalgae filtered from 30 litres of surface water were made up to a 10 ml volume concentrate. One (1) ml of this sample was transferred to the Sedgewick-Rafter Counting Cell (volume of this chamber is 1ml).

4Petersen, C. G. J.1913. “Valuation of the Sea. II. The Animal Communities of the SEA BOTTOM and their Importance for Marine Zoogeography”. Danish Biol. Sta., Repts., 21(1–44). 5Jones, N.S.1950. Marine Bottom Commuities. Biological Reviews. 25(283-313). 6Rhoads, D. C. 1974. Organism-Sediment Relations on the Muddy Sea Floor. Oceanogr. Mar. Biol. Ann. Rev. 12(263–300).

http://web.vims.edu/bio/shallowwater/benthic_community/benthic_microalgae.html

http://web.vims.edu/bio/shallowwater/ecosystem_processes/detritus_formation.html

http://web.vims.edu/bio/shallowwater/benthic_community/microbes.html

http://web.vims.edu/bio/shallowwater/benthic_community/microbes.html

http://web.vims.edu/bio/shallowwater/human_effects/management_approaches.html

http://web.vims.edu/bio/shallowwater/ecosystem_processes/secondary_production.html

http://web.vims.edu/bio/shallowwater/ecosystem_processes/secondary_production.html



The number of microalgae present in all the thousand grids in the Sedgewick-Rafter Counting Cell was calculated. Counting was repeated for three times and an average was taken. The total number of planktonic algal species present in one (1) litre of water sample was calculated using the formula:

N = n x v V

Where, N = No. of planktonic algae per litre of water filtered n = Average no. of planktonic algae in one (1) ml of sample

v = Volume of plankton concentrates in ml V = Total volume of water filtered in litre

Identification of phytoplankton: Phytoplankton groups were identified based on standard keys (Allen and Cupp, 1935;Venkataraman, 1939;Cupp, 1943;Subrahmanyan, 1946;Hustedt, 1955;Desikachary, 1959;Hendey, 1964;Simonsen, 1974;Gopinathan, 1984; Jin Dexiang et al., 1985;Desikachary and Sreelatha, 1989;Hallegraeff et al., 1995; Tomas et al., 1997).

Zooplankton: Samples were collected from the surface waters along each location by horizontal surface towing of plankton net (Bongo Net, mouth area 0.25m2, mesh size 200µm) for 10 minutes. Samples were collected in 250 ml plastic bottles and preserved in 4% buffered formaldehyde which was later used for qualitative and quantitative analysis following Goswami and Padmavathi (1996)7.

Zooplankton biomass is expressed as ml/1000m3 by using the formula as given below:

Biomass = Displacement Volume/ Volume of Water Filtered

The zooplankton taxa were sorted from the whole sample or from an aliquot (50%) using a Folsom Splitter (Sell and Evans, 1982) and counted under a stereomicroscope. The zooplankton was primarily sorted to the major taxonomic groups according to the standard identification manuals (Newell and Newell, 1973; Todd and Laverack, 1991). The keys employed include the works of Toddet al., (1996), Wilson (1932), Davis (1955), Kasthurirangan (1963), Krishnapillai (1986) and Wickstead (1965).

The abundance is expressed as ‘ind / 1000 m3’ using the formula:

Abundance (ind/1000 m3) = No. of individuals of the particular taxa /volume of water filtered

Benthos: The sediment for analysis of benthos, both macro and meiofauna has been collected using a standard Van-Veen Grab Sampler, with an area of 0.2 m2 (Anastasio Eleftheriou and Alasdair McIntyre, 2005; Holme and McIntyre, 1971).

Macro-benthos: Macrobenthos were separated by sieving the sediment through 0.5 mm sieve. The organisms retained in the sieve are considered as macrobenthos. The entire macrobenthic specimen were picked out from the sediment and sorted out. Before sieving, samples were

7Gowsami and Padmavathi, 1996. Zooplankton Production, Composition and Diversity in the Coastal Waters of Goa. Indian J. Mar. Sci., 25(91-97).



treated with Rose Bengal in order to enhance the colour contrast of the organisms. Identification was carried out for major groups such as polychaetes and molluscs. The standard as well as published references were used for identification of different macrofauna (Fauvel, 1953 and other published works). Identification was followed by count of the individuals per species for polychaetes and molluscs and group for rest of the organisms.

Meio-benthos: For the analysis of meiofauna, graduated glass corer, 30 cm long with an inner diameter of 2.5 cm was used to sub sample meiofauna from 0.2m2 Van-Veen grab haul. The corer was inserted into the undisturbed sediment, to a depth of 4 cm and samples were transferred into labeled plastic containers containing 5% neutral formalin. The sediment containing the meiofauna was stained with Rose Bengal biological stain (0.1 g in 100 ml of distilled water). The organisms were separated and enumerated using a binocular microscope and preserved in 4 % neutral formalin (Giere, 2008). The numerical abundance of organisms was extrapolated in to no./10cm2. The standard as well as published references were used for identification of the different meiofauna (Giere, 2008).

A) Diversity Indices: Species diversity index considers the number of species in a sample and also their relative abundance. The index is high in samples that have large numbers of unique species.

(i) Shannon - Wiener index (H’)

In the present study, the data were analyzed for diversity index (H’) using the following Shannon - Wiener’s formula (1949):

H’ = -Ʃ S Pi log 2 Pi….. i = 1

This can be rewritten as,

H’ = 3.3219 (N log N -Ʃni -log ni)/N

Where, H’ = Species diversity in bits of information per individual ni = Proportion of the samples belonging to the ith species (Number of individuals of the ith species) N = Total number of individuals in the collection

(ii) Margalef Richness Index (d) (Margalef, 1958)

The Margalef Richness Index (d) is given by the formula:

d = (S-1) / log N

Where, S = Number of taxa

N = No. of individuals

(iii) Pielou’s evenness index (J’)

The equitability (J’) was computed using the following formula of Pielou (1966):

J’ = H’/Lod2S or H’/Ins

Where, J’ = Evenness H'= Species diversity in bits of information per individual S = Total number of species



(iv) Simpson Index (D) (Simpson, 1949)

The Simpson Index (D) is given by: D = 1 – λ, Where, λ = Ʃ Pi2

Pi = ni/N Here, ni= Number of individuals of i, i2,….. N = Total number of individuals

B) Similarity Indices

(i) Cluster Analysis: Cluster analysis was done to find out the similarities between groups. The most commonly used clustering technique is the hierarchical agglomerative method. The results of this are represented by a tree diagram or dendrogram with the ‘x’ axis representing the full set of samples and the ‘y’ axis defining the similarity level at which the samples or groups are fused. Bray - Curtis coefficient (Bray and Curtis 1957) was used to produce the dendrogram. The coefficient was calculated by the following formula:

Sjk = 100 Σ(i=1 to p) 2min(yij,yik) Σ(i=1 to p) (yij + yik)

Where, yij = Entry in the ith row and jth column of the data matrix i.e. the abundance or biomass for the ith species in the jth sample (i =1, 2, ..., p; j = 1, 2, ..., n)

yik= Count for the ith species in the kth sample min (.,.) = Minimum of the two counts

The separate sums in the numerator and denominator are both over all rows (species) in the matrix.

Analysis Results

The location-wise abundance of the various species of phytoplankton, zoo planktons, benthic meio and the chlorophyll productivity are given in Table 3.8. The abundance of zooplankton genera, Phytoplankton genera and Benthic phylum and group are separately shown in Table 3.9 and Table 3.10 & 3.11 respectively. The graphical analysis of the abundance of the species, location-wise, is shown in Figure 3.14.



Table 3.8: Marine Biological Environment Analysis

S. No. Parameters Unit SS1 at B9-1 SS2 at B9-2 SS3 at B9-3 SS4 at B7 SS5 at BRC

S B S B S B S B S B

1. Chlorophyll-a mg/m³ 2.72 2.85 2.91 2.81 3.04 1.91 3.49 1.95 6.81 6.39

2. Primary Productivity- Gross mgC/m³/d 680 -- 640 -- 490 -- 600 -- 490 --

3. Primary Productivity- Net mgC/m³/d 190 -- 120 -- 150 -- 70 -- 80 --

4. Phyto-plankton No./ml 199.6 100 190.8 76 189.8 181.4 287.6 247 932.4 519.8

5. Zooplankton No./500 ml 62 -- 64 -- 39 -- 37 -- 48 --

6. Benthic Meio No./m -- 25 -- 19 -- 12 -- 60 -- 17



Table 3.9: Abundance of Zooplankton Species

Speciation of Zooplankton Species Observed (Surface) S. No. Zooplankton Genera SS-1 SS-2 SS-3 SS-4 SS-5

1 Acetes sp. + + + + - 2 Amphioods + - - + - 3 Appendicularians - - - - - 4 Cephalopods - - - - - 5 Chaetognaths + + + - - 6 Cladocerans - - - - - 7 Copepods + + + + + 8 Ctenonhores - - - + - 9 Cumaceans - - - - -

10 Decapod larvae + + + + + 11 Doliolids - - - - - 12 Euphausids - - - - - 13 Foraminiferans + - - - - 14 Fish Eggs - - + - - 15 Fish Larvae + + + + + 16 Gastropods + + + + + 17 Heteropods - - - - - 18 Isopods + + + + + 19 Lamellibranchs + + + + + 20 Lucifer sp. + + + + + 21 Marine Insects - - - - - 22 Medusae + - + + + 23 Mysids + + + + - 24 Ostracods - - - - - 25 Polychaetes + + - + - 26 Pteropods - - - - - 27 Pvcnoeonids - - - - - 28 Salpids - - - - - 29 Siphonophores + + - + - 30 Stomatopods - - - - -

Table 3.10: Abundance of Phyto-plankton Species (S-Surface, B-Bottom)

Speciation of Phytoplankton Species Observed

S. No. Phytoplankton Genera SS-1 SS-2 SS-3 SS-4 SS-5

1 Amphiprora S B S B S B S B S B - - + + - + - + - -

2 Amphora + - - - - - - - - -



Speciation of Phytoplankton Species Observed

S. No. Phytoplankton Genera SS-1 SS-2 SS-3 SS-4 SS-5

3 Anabaena - - - - - - - - - + 4 Asterionellopsis + - + + - + + + - - 5 Ceratium - + - - - - + - - + 6 Chaetoceros + + + + + + + + - - 7 Corethron - - - - + - + + - - 8 Cyclotella - - - - - - - - + + 9 Cylindrotheca + + + + + + + + + + 10 Diploneis + + - - - - - - - - 11 Ditylum + + + + - + + + - - 12 Gonyaulax - - + - - - + + + - 13 Guinardia + + + + + + + + + + 14 Gymnodinium + + + - + + + + - - 15 Gyrodinium - - - + + + + + + + 16 Gyrosisma - - - - - - - - - + 17 Leptocylindrus - - - - - - + - + + 18 Lithodesmium - - - - + + + - - - 19 Mallomonas - - - - - - - - + - 20 Melosira + - - - - - - - - - 21 Navicula - + - - - - + - + + 22 Nitzschia + + - + + + + - - + 23 0dontella + + + + + + + + + + 24 Peridinium - - - - + - + - + + 25 Pleurosigma + + + + + - + + + + 26 Prorocentrum - + - - + - - - + - 27 Protooeridinium - + - - + - + - + - 28 Pseudo-nilzschia + + + + + + + + + + 29 Rhizosolenia - + + - + + + + + + 30 Skeletonema + - + - + + - - + + 31 Surirella - + + - + + - - + + 32 Thalassionema + + + + + - + + + - 33 Thalassiosira + + + + + + + + + + 34 Thalassiothrix - - - - - - - - + - 35 Triceratium - - - + + + - - - - 36 Trichodesmium - - - - - - - - - +



Table 3.11: Abundance of Benthic Species (Bottom)

Speciation of Benthos Species Observed Sl. No. Phylum Groups SS-1 SS-2 SS-3 SS-4 SS-5

1. Phoronida Phoronids - - - - - 2. Mollusca Gastropoda - - + - + 3. Mollusca Scaphopoda - - - - - 4. Mollusca Pelecypods + + - - + 5. Annelida Polychaetes + + - + - 6. Sipuncula Sipunculid - - - - + 7. Arthropoda Isoooda - - - + - 8. Arthropoda Brachyura + - + - - 9. Arthropoda Amphipods - - - - - 10. Arthropoda Cumaceans - - - - - 11. Arthropoda Mysids - - - - - 12. Arthropoda Sergestids + - - + - 13. Arthropoda Penaeid shrimps - - - - - 14. Arthropoda Tanaids - - - - - 15. Echinodermata Ophiuroids - - - - - 16. Chordata Fish larvae + - - - - 17. Nemetrea Nemetrea - - - - +

Concentration of Chlorophyll-a at Various Sampling Locations

(Surface & Bottom)

2.72 2.85 2.91 2.81 3.04

1.91

3.49

1.95

6.816.39

0

1

2

3

4

5

6

7

8

Ch

loro

ph

yll-

aC

on

cen

trat

ion

(m

g/m

³)



Adundance of Benthic Meio at Various Sampling Locations (Bottom)

Abundance of Zooplankton at Various Sampling Locations (Surface)

Abundance of Phytoplankton at Various Sampling Locations (Surface)

SS1 At B9-1 (Bottom)

19%


14%


9%

SS4 At B7 (Bottom)

45%

SS5 At BRC (Bottom)

13%

SS1 At B9-1 (Surface)

25%

SS2At B9-2 (Surface)

26%

SS3 At B9-3

SS4 At B7 (Surface)

15%

SS5 At BRC (Surface)

19%


11%

SS2At B9-2 (Surface)

11%


10%

SS4 At B7 (Surface)

16%

SS5 At BRC (Surface)

52%



Abundance of Phytoplankton at Various Sampling Locations (Bottom)

Figure 3.14: Graphical Analysis of Marine Biological Characteristics

3.6.1.4 Marine Fisheries:

The dominant fish species found in the study area are listed below in Table 3.12:

Table 3.12 List of Fish Species in the study area

S. No. Species Name Family Habitat

1 Abalistes stellaris Starry triggerfish Balistidae Demersal 2 Acanthocybium solandri Wahoo Scombridae Pelagic-oceanic

3 Acanthopagrus arabicus Arabian yellowfin seabream

Sparidae Pelagic-neritic

4 Acanthoplesiops indicus Scottie Plesiopidae Demersal 5 Acroteriobatus salalah Salalah guitarfish Rhinobatidae Demersal

6 Aldrovandia affinis Gilbert’s halosaurid fish Halosauridae Benthopelagic

7 Alepisaurus ferox Long snouted lancetfish Alepisauridae Bathypelagic

8 Alopias vulpinus Bigeye thresher Alopiidae Pelagic-oceanic

9 Amblyeleotris downingi Downing’s shrimpgoby Gobiidae Demersal

10 Amblyraja reversa Reversed skate Rajidae Bathydermersal

11 Anodontostoma chacunda Chacunda gizzard shad Clupeidae Pelagic-neritic

12 Branchiostegus Freckled tilefish Malacanthidae Demersal 13 Carcharhinus plumbeus Sandbar shark Carcharhinidae Benthopelagic

14 Pateobatis bleekeri Bleeker’s whipray Dasyatidae Benthopelagic

15 Thryssa vitrirostris Orangemouth anchovy Engraulidae Pelagic-neritic

(Source - https://www.fishbase.de/TrophicEco/FishEcoList)


9%SS2 At B9-2

(Bottom)7%


16%

SS4 At B7 (Bottom)

22%

SS5 At BRC (Bottom)

46%

https://www.fishbase.de/TrophicEco/FishEcoList

44

AANNTTIICCIIPPAATTEEDD

IIMMPPAACCTTSS && MMIITTIIGGAATTIIOONN MMEEAASSUURREESS



1. ANTICIPATED IMPACTS AND MITIGATION MEASURES

4.1 IDENTIFICATION AND ASSESSMENT OF IMPACTS

The main purpose of Environmental Impact Assessment (EIA) study is to identify and assess potential impacts due to the proposed project on the environment, thereby proposing suitable mitigation measures to minimize the adverse impacts. The key supporting information required for the impact identification and assessment are detailed description of both the project activities as provided in Chapter 2 and the baseline setting of the environment of the proposed project site as depicted in Chapter 3. The information presented in these chapters facilitates the identification of the interactions between the planned drilling, installation and operation phases with the environment. The methodology adopted for the impact assessment is shown in Figure 4.1.

Figure 4.1: Methodology for Environmental Impact Assessment

In this section, the interactions between the project activities and the environment are outlined, impacts on environmental components due to the project activities based on the interaction are assessed and mitigation measures are suggested.

44

Description of the Project (Installation

and Operation Phases)

Hazard Characterisation

Environmental Sensitivities

Hazard Identification

Identification of Project - Environmental Interactions

Description of the Environment

Environmental Impact Assessment

Mitigation Measures



The activities which will be carried out both during installation and operation phases of the proposed project are as follows:

• Positioning and deployment of rig. • Power generation at site. • Drilling operations. • Laying of sub-sea pipelines • Installation of Wellhead platforms. • Well completion. • Transport of equipments and materials. • Waste Water discharges. • Solid waste generation. • Fuel storage and handling. • Wells hook-up. • Commissioning and start-up. • Routine Operation and Maintenance.

4.2 INTERACTION OF PROJECT ACTIVITIES WITH THE ENVIRONMENT

After identification of different activities during drilling and installation and operation phases, the next step is delineation of interaction between the identified activities with the environment. Table 4.1 shows the Environment Sensitivities and Activity Interaction Matrix for the proposed project. From the table, it can be inferred that, there are some domain where the impact will be significant and on some domains the impact is beneficial. The domains where the impacts are significant can be easily minimized by applying suitable mitigation measures as discussed in later sections.

Table 4.1: Interaction Matrix for the Proposed Project

PROJECT ACTIVITIES

Posi

tioni

ng a

nd D

eplo

ymen

t of

Rig

Pow

er G

ener

atio

n at

Site

Dri

lling

Ope

ratio

n

Pipe

line

Ope

ratio

n

Inst

alla

tion

of W

ellh

ead

Plat

form

s

Wel

l Com

plet

ion

Tra

nspo

rt o

f Equ

ipm

ents

an

d M

ater

ials

Was

tew

ater

Disc

harg

es

Solid

Was

te G

ener

atio

n

Fuel

Sto

rage

and

Han

dlin

g

Physical Environment Air Quality - - -

Noise - - - -

Water Quality - - - - - - -

Sediment Quality - - - - - - - - -

Marine Biological Environment

Aquatic Flora - - - - - - - - - -

Aquatic Fauna - - - - - - - - - -

Local Fish Population - - - - - - - - - -

Socio-Economic Environment

Activity

Env

iron

men

tal

Sens

itivi

ties



PROJECT ACTIVITIES

Posi

tioni

ng a

nd D

eplo

ymen

t of

Rig

Pow

er G

ener

atio

n at

Site

Dri

lling

Ope

ratio

n

Pipe

line

Ope

ratio

n

Inst

alla

tion

of W

ellh

ead

Plat

form

s

Wel

l Com

plet

ion

Tra

nspo

rt o

f Equ

ipm

ents

an

d M

ater

ials

Was

tew

ater

Disc

harg

es

Solid

Was

te G

ener

atio

n

Fuel

Sto

rage

and

Han

dlin

g

Physical Environment Occupational Exposure &

General Safety - -

- - -

Economy +

Legends + Beneficial Impact - Adverse Impact

The proposed development project is located in shallow water far away from the shore within Mumbai offshore basin. Thus, there will be no threat to the nearby coastlines or habitations. As per the above interaction matrix it is inferred that the significant impacts can be seen mainly for marine water, sediment, ecological environment, air and noise environment. However, these impacts will be short termed and, can be minimized by implementing effective mitigation measures.

The following sections explain the detailed impacts of proposed project on each environmental sensitivity during drilling and installation phase (laying of sub-sea pipelines and installation of wellhead platforms) as well as in operation phase. Subsequently, these impacts are evaluated, and their mitigation measures are suggested.

4.2.1 Impact on Air Environment

a) Drilling and Installation

During the installation and drilling period, there will be activities taking place like operation of diesel generator (DG), emergency venting and gas flaring. This may lead to the emission of pollutants in air leading to the degradation of the air environment. The most likely occurring pollutants from these sources are NOx, PM₁₀, and SOx. However, high wind speed in the open sea area shall lead to greater dilution of pollutants, which shall increase with increasing distance from the source. Moreover, absence of sensitive receptors shall render the impacts due to air emission as negligible.

b) Operation Phase

Once the offshore wells are drilled, it will be connected to wellhead platforms through sub-sea pipelines for processing. Un-manned wellhead platforms will be operated and thus no human activities are envisaged in normal operations. Only life of field services and certain mandatory sub-sea maintenance activities are envisaged, which are of short duration in nature. Hence, no major environmental impacts are envisaged.

These platforms will be powered through Solar power. Thus, emission of pollutants during the operation is not envisaged.

Activity E

nvir

onm

enta

l Se

nsiti

vitie

s



4.2.2 Impact on Noise Quality

a) Drilling and Installation Phase

Noise is likely to be generated to the generation of large machinery (large power generation units (diesel engines/gas turbines), fluid pumps, mud pumps) equipment and transportation vessels. However, these impacts shall not cause any physical damage to the marine organisms as the propagation of sound through water is generally affected by spreading (distance) losses and attenuation (absorption) losses with sound energy decreasing with increasing distance from the source. Therefore, the impacts on the marine fauna due to noise generation during the project activities have been envisaged to be minimal.

b) Operation Phase

Very less noise is likely to be generated during the operation phase due to operation of wellhead platforms and intermittent movement of helicopter and supply vessels used for inspection or maintenance activities. However, these impacts shall not cause any physical damage to the marine organisms because of their tendency to avoid operation areas producing continuous and semi-continuous noise.

4.2.3 Impact on Marine Water Quality


The deployment of rig in the offshore and other sub-sea infrastructure and facilities has been foreseen to cause short-term impact. The displacement of sea-bed sediments may lead to oxidation of anoxic intertidal and offshore mud, leading to local chemical changes in water quality by a subsequent decrease in pH and increase in BOD levels. However, these impacts have been envisaged to be local and temporary, and its expected the water will regain its original capacity within a short span. The water quality may also be affected by the solid/liquid discharges and accidental spillage of chemicals/oil/lubricants during project activities like deployment of rigs, operation of generators and transportation of vessels. The main physical impact on sea water from the discharge of drill cuttings and fluids are associated with a localized increase in water turbidity near discharge points and minor changes in the local water quality.

b) Operation Phase

The water quality of the project site could be affected due to accidental spillage of chemicals/oil/lubricants from the operation wells and/or transfer of hydrocarbons through the sub-sea pipelines. However, adequate engineering designs will be adopted to avoid any leakages/spillages from the operation activities. Oil Spill Contingency Plan (OSCP) (given in EMP) will be implemented in the event to any accidental leakage/spillage.



4.2.4 Impact on Sediment Quality


Project activities like deployment of rigs, wellhead installations, laying of sub-sea pipelines and other sub-sea infrastructures may cause local and temporary disturbance to the sea-bed due to sediment suspension and changes in the sea-bed morphology. However, these impacts shall not contaminate the sediments as suitable safety and control measures will be adopted to mitigate the risk of sediment contamination from these sources.

b) Operation Phase

Sediment quality is less likely to be affected due to operational discharges (liquid and solid discharges) or accidental spillage of fuel/chemical/lubricant during the project activities. However, these impacts shall be mitigated by adoption of suitable measures and implementation of waste management plan.

4.2.5 Impact on Marine Biological Quality a) Drilling and Installation Phase

The marine life is likely to get disturbed due to the drilling and installation activities, the noise generated from the operation of large machinery (diesel engines/gas turbines/fluid pumps/mud pumps) equipment, and transportation vessels. However, these impacts will be temporary in nature and shall not cause any physical damage to the marine organisms as the propagation of sound through water is generally affected by spreading (distance) losses and attenuation (absorption) losses with sound energy decreasing with increasing distance from the source. Also, the suspended particles in water will settle in a short span of time. Therefore, the anticipated impacts on the marine organisms shall be considered minimal.

b) Operation Phase

The presence of sub-sea infrastructure, wellhead platforms and sub-sea pipelines are likely to have an impact on the marine ecology. The sub-sea infrastructure shall act as a physical hindrance to the marine organisms and displacement of marine species in immediate vicinity leading to direct habitat loss. The operational activities is also likely to have an impact on the benthos in the benthic zone leading to its destruction, smothering or displacement. Even though the impacts during the initial phase have been envisaged to be significant, the region is likely to regain its ecological balance in a short-span of time due to the adaptable nature of the marine organisms. Activities like accidental spillage of chemicals/oils/lubricants/operational discharges into the sea will also have a significant impact on the marine biodiversity.

4.2.6 Socio-Economic Environment

The proposed project activities is likely to have an impact on the existing socio-economic profile of the region:

• Generation of temporary employment in the region due to the requirement of workers in offshore base activities, supply and transport of raw materials & equipment and other ancillary works.



• Likely creation of long-term employment opportunities during the operational life of the fields. Besides this, the discovered hydrocarbons will help in contributing to the ongoing efforts of the Government to meet the national demand of petroleum resources.

4.3 IMPACT EVALUATION

Offshore installation and drilling activities are likely to increase the air emissions by medium magnitude. However, the impacts of these emissions have been envisaged to be insignificant due to highly dispersive environment of offshore location and absence of sensitive receptors. Thus, the overall impact on local air quality shall be of minor significance. Noise generated during the project activities shall not adversely impacts marine fauna, however, some marine mammals (within 1 to 3 km radius from the source) may be predicted to exhibit avoidance reactions to the larger project vessels as they may have greater ability to disturb in relation to their sound level than the ongoing drilling activities. However, no physical damage has been envisaged and thus the anticipated impacts on marine organisms shall be minimal due to their avoidance approach towards continuous and semi-continuous noise (Nedwell et al., 2004 and Thomsen et al., 2006). Impacts on marine water quality has been envisaged to be insignificant as the wastewater and solid discharges from the project activities shall be treated to meet requirements of stipulated standards prior to its disposal. However, deployment of rig, and installation of offshore structures shall temporarily increase the turbidity levels in local marine environment, but it has been envisaged that the region is expected to regain its original characteristics in short span of time.

Project activities shall temporarily affect the local seabed habitats and species, but the area affected being a small percentage of the total area of similar habitats in this offshore location. Also, the negative impacts of seabed structures on benthic communities are assessed as being of minor significance.

4.4 IMPACT SIGNIFICANCE

Evaluation of impacts signifies the potential impacts in terms of its likelihood nature as per the following criteria:

a. Intensity of the impact: This classification is based on the intensity, whether the impact has high, moderate or low intensity.

b. Spatial Distribution: The impacts are further classified based on their spatial distribution, i.e. local, when impacting an area of approximately 1 km radius from the project area, moderate spread, when impacting an area of 1 to 2 km radius and regional beyond 2 km.

c. Temporal Scale: The impacts are classified as short term, moderate term and long term in terms of their existence in temporal scale. Impacts less than 1-year existence is short term, while those with 1 to 3 years is of moderate term and more than 3 years is of long term.

d. Nature of Impact: The negative impacts are termed as adverse impacts while positive impacts as beneficial.

The significance of environmental impacts of various involved activities has been evaluated based on the criteria outlined in Table 4.2.



Table 4.2: Impact Significance Criteria

Impact Significance Criteria

Major Adverse When the impact is of high intensity with high spread and high duration/high intensity with medium spread and medium duration.

Moderate Adverse When the impact is of moderate intensity with high spread and high duration/high intensity with low/ moderate spread and low duration.

Minor Adverse When the impact is of low intensity but with moderate spread and moderate duration/moderate intensity

Insignificant Adverse When the impact is of low intensity, low spread Beneficial When the impacts are positive

Based on the above-specified criteria, Tables 4.3 describes the potential environmental impacts due to development drilling in the cluster fields in the Mumbai Offshore Basin and associated activities, without mitigation measures. It is important to note that one activity may have varying impacts on different receptors i.e. different components of the environment. To avoid repetitions, this section describes various activities, which may have wide impacts on many receptors.

Table 4.3: Potential Environmental Impacts of Proposed Project Activities (Without Mitigation Measures)


Nature of Likely Impacts Impact Significance

Low

Inte

nsity

Mod

erat

e In

tens

ity

Hig

h In

tens

ity

Loca

l Spr

ead

Mod

erat

e Sp

read

Reg

iona

l Spr

ead

Shor

t Ter

m

Mod

erat

e Te

rm

Long

Ter

m

Adv

erse

Ben

efic

ial

Insi

gnifi

cant

Min

or

Mod

erat

e

Maj

or

Physical Environment Air Quality □ □ □ □ □ Noise □ □ □ □ □ Water Quality □ □ □ □ □ Sediment Quality □ □ □ □ □ Marine Biological Environment Aquatic Flora □ □ □ □ □ Aquatic Fauna □ □ □ □ □ Local Fish Population □ □ □ □ □ Socio-Economic Environment Local Economy □ □ □ □ □

4.5 IMPACT MITIGATION MEASURES

4.5.1 Air Environment a. Good operational controls and high level of monitoring shall be built into the design

operational aspects of the project.



b. Regular maintenance of engines and DG sets shall be ensured to keep the environmental impact minimum.

c. The DG sets shall comply with the applicable emission norms. d. Regular maintenance of the transportation vessels to be ensured so as to minimize level of

emission in the environment. e. Regular ambient air quality monitoring must be carried out according to the specified

norms.

4.5.2 Water Environment

a. The sewage shall be treated on-board of the rig according to the MARPOL Regulations. Residual chlorine of the treated sewage shall not exceed 1mg/L before disposal.

b. Oily wastewater from drainage system shall be treated using on-board oil traps and will be disposed to sea according laid by Central Pollution Control Board (CPCB). According to MARPOL Regulations, the discharge of oil content (without dilution) into sea shall not exceed 15 parts per million (ppm).

c. Usage of only low toxicity chemicals must be ensured on-board of the rig and transportation vessels.

d. Bulk discharge of drilling fluid in offshore is prohibited except in emergency situations. According to a notification issued by MoEF dated 30th August 2005, G.S.R. 546 (E), Water-Based Mud (WBM)/Oil-Based Mud (OBM)/Synthetic Oil Based Mud (SOBM) should be recycled to a maximum extent. Unusable portion of WBM/SOBM will be discharged offshore into sea intermittently, at an average rate of 50 bbl/hr/well from a platform so as to have proper dilution and dispersion without any adverse impact on marine environment.

e. Oil drilling operators must ensure to maintain daily record of discharge of drill cutting & drill fluid to offshore and also monitor daily the effluent quality.

f. In case of oily cuttings, they will be transported on shore for appropriate disposal.

4.5.3 Biota

a. The baseline information on existing marine species in the area shall be obtained from state/ district/regional level authorities and other sources in an effort to reduce the potential adverse impacts of the project and future activities on marine species.

b. All precautionary measures shall be adopted to minimize disturbance to the marine animals due to deployment and operations of offshore wells.

4.5.4 Occupational Health Hazards from Noise Pollution

a. On-site workers working near high noise equipment shall use personal protective equipment (PPE) to minimize their exposure to high noise levels.

b. Good working practices shall be implemented to reduce noise impact on the health and environment.

4.5.5 Noise due to Drilling Activities

a. Mobile noise sources such as rig and vessels shall be routed in such a way that there is minimum disturbance to receptors.

b. Avoid loud, sudden noises, wherever possible. Integral noise shielding shall be used where practicable and applicable.



c. Rubber padding/noise isolators shall be provided at equipment/machinery used during the project activities.

d. Regular maintenance of all equipment and transportation vessels shall be ensured. Idling of vessels or equipment shall be avoided when not in use.

4.5.6 Waste Generation and Management

The site would develop and adopt proper system for the management, storage and disposal of the hazardous and non-hazardous waste, for example measures such as:

• Solid waste including domestic waste, combustible and recyclable waste shall be collected, segregated and stored in specified containers and shall be transferred to authorized contractors for their disposal.

• Hazardous waste such as medical waste, waste lube/system oil from machinery, used oil from generator set shall be handled as per Hazardous Wastes (Management, Handling and Trans-boundary Movement) Rules, 2016. The waste will be carefully stored in drums and transported to MoEF approved recyclers for its final disposal. All precautions will be taken to avoid spillage from the storage.

Table 4.4 below provides the potential environmental impact due to drilling and related activities in the cluster fields in the Mumbai Offshore Basin.

Table 4.4: Potential Environmental Impacts of Proposed Project Activities (with Mitigation Measures)


Nature of Likely Impacts Impact

Significance

Low

Inte

nsity

Mod

erat

e In

tens

ity

Hig

h In

tens

ity

Loca

l Spr

ead

Mod

erat

e Sp

read

Reg

iona

l Spr

ead

Shor

t Ter

m

Mod

erat

e Te

rm

Long

Ter

m

Adv

erse

Ben

efic

ial

Insi

gnifi

cant

Min

or

Mod

erat

e

Maj

or

Physical Environment Air Quality □ □ □ □ □ Noise □ □ □ □ □ Water Quality □ □ □ □ □ Sediment Quality □ □ □ □ □ Marine Biological Environment Aquatic Flora □ □ □ □ □ Aquatic Fauna □ □ □ □ □ Local Fish Population □ □ □ □ □ Socio-Economic Environment Local Economy □ □ □ □ □

55

EENNVVIIRROONNMMEENNTTAALL

MMOONNIITTOORRIINNGG PPLLAANN



2. ENVIRONMENTAL MONITORING PROGRAM

5.1 INTRODUCTION

An Environmental Monitoring Program provides a delivery mechanism to address the adverse environmental impacts of a project during its execution, to enhance project benefits and finally to introduce standards of good practices to be adopted. An environmental monitoring plan is important as it provides useful information and helps to:

• Assist in detecting the development of any unwanted environmental situation during drilling and installation or operation phases, and thus, provides opportunities for adopting appropriate control measures.

• Define the responsibilities of the project proponent, contractors and environmental monitors and provides means of effective communication of environmental issues among them.

• Define monitoring mechanism and identify monitoring parameters.

• Evaluate the performance and effectiveness of mitigation measures proposed in the Environment Management Plan (EMP) and suggest improvements in management plan, if required.

From the monitoring point of view, the important parameters are resource inventory, water quality, sediment quality, noise quality, and biological components. The suggested monitoring details are outlined in the following sections.

5.2 ENVIRONMENTAL MONITORING PROGRAM

An environmental monitoring program is suggested to monitor environmental parameters during the project period Table 5.1 below.

55



Table 5.1: Environmental Monitoring Program

Receptor Location Monitoring Mechanism Monitoring and

Reporting Frequency During Drilling and Installation (laying of sub-sea pipeline and installation of Wellhead Platform) Natural Resource Project Site

(Operation areas) • Quantity of each type of material used

including water consumption. • Quantity of fuel used.

Daily during Drilling

Drilling wastes Drilling Locations.

• Offshore discharge of unusable WBM, if required, on meeting EP standards at a intermittent rate of 50bbl/hr

• Any other waste to be stored on rig & brought onshore for disposal.

• Daily monitoring & recording of quantity

• Monitor and record the generation quantity on daily basis.

Oil Spills

Drilling Locations.

• Inventory of all oil spills/leakages and quantity of each spill.

• Availability of facilities according to Oil Spill Contingency Plan (OSCP).

• Presence of Oil Drip Plans in potential oil leakages areas.

Daily during Drilling Operation.

Noise & Vibration

Project Site. (Operation areas)

• Noise level monitoring. • Machineries maintenance. • No machinery running when not required. • Use of ear plug by workforce.

Weekly during Drilling and Installation phase.

Water Quality

• Upto 1 km radius from Drilling location/Wellhead platform site.

• At every 5 km stretch of the sub-sea pipeline and locations within 1 km radius of the pipeline.

• pH, Conductivity, TSS, TDS, Heavy Metals, BOD, COD, Oil & Grease, Total Petroleum, Hydrocarbons (TPH) and Petroleum Aromatic Hydrocarbons (PAHs).

Once during Drilling and Installation phase.

Sediment Quality • Upto 1 km radius from Drilling location/Wellhead platform site.

• Texture, Organic matter, Nitrogen, Phosphorous, Oil & Grease, Heavy Metal




Receptor Location Monitoring Mechanism Monitoring and Reporting Frequency


Concentration, Total Petroleum, Hydrocarbons (TPH) and Petroleum Aromatic Hydrocarbons (PAHs).


• Upto 1 km radius from Drilling location/Wellhead platform site.


• Phytoplanktons, Zooplanktons, Benthos and Chlorophyll estimation.


Project Site (Operation areas)

• Visual observations of the marine flora and fauna will be done in routine through the rig and surveillance vessels on round.

Daily during Drilling and Installation phase.

Operation Phase Water Quality

• Upto 1 km radius Well/Wellhead platform site.


• pH, Conductivity, TSS, TDS, Heavy Metals, BOD, COD, Oil & Grease, Total Petroleum, Hydrocarbons (TPH) and Petroleum Aromatic Hydrocarbons (PAHs).

Once in a year.

Sediment Quality • Upto 1 km radius Well/Wellhead platform site.


• Texture, Organic matter, Nitrogen, Phosphorous, Oil & Grease, Heavy Metal Concentration, Total Petroleum, Hydrocarbons (TPH) and Petroleum Aromatic Hydrocarbons (PAHs).

Once in a year.


• Upto 1 km radius Well/Wellhead platform site.


• Phytoplanktons, Zooplanktons, Benthos and Chlorophyll estimation.

Once in a year.



The pre and post operational monitoring programme shall be carried out under the supervision of the AWEL. The water, sediment and ecological monitoring (planktons, chlorophyll, and benthos) shall be carried out as per the MoEF&CC guidelines by engaging MoEF&CC/ NABL accredited laboratories only.

The noise monitoring will be carried out on weekly basis using automated noise data logger. Noise data logger shall be made available at rig or the offshore supply vessel. Inventory of natural resources and wastes or spills/leakages and visual observation of marine flora & fauna shall be carried out internally. Training on Environmental monitoring (resource inventory, waste or spills/leakage inventory, visual observations of marine species, etc) and other HSE related aspects shall be provided to the staff engaged for drilling and Installation activities and shall be provided by the AWEL’s HSE Officer.

5.3 BUDGET

The monitoring and evaluation process will require a contingency budget. The cost required for the Environmental Monitoring Program both for Drilling/ Installation Phase and Operation phases are given in Table 5.2 and 5.3 respectively.

Table 5.2: Budget for Environmental Monitoring Plan during Drilling/ Installation

Sl. No.

Attribute Parameters

Per Sample Cost

(in INR) (A)

No. of Sample

(B)

Total Cost (in INR)

(D) (A*B=C)

1. Water pH, Conductivity, TSS, TDS, Heavy Metals, BOD, COD, Oil & Grease, Total Petroleum, Hydrocarbons (TPH) and Petroleum Aromatic Hydrocarbons (PAHs).

8000 30 2,40,000

2. Sediments pH, Texture, Organic matter, Nitrogen, Phosphorous, Oil & Grease, Heavy Metal Concentration, Total Petroleum, Hydrocarbons (TPH) and Petroleum Aromatic Hydrocarbons (PAHs).

8000 30 2,40,000

3. Ecological Phytoplanktons, Zooplanktons, Benthos and Chlorophyll estimation.

9000 30 2,70,000

4. Occupational Health and

General check-up, respiratory and auditory

2,00,000 - 2,00,000



Sl. No.


Per Sample Cost

(in INR) (A)

No. of Sample

(B)

Total Cost (in INR)

(D) (A*B=C)

Safety ailment. Total 9,50,000/-

Table 5.3: Budget for Environmental Monitoring Plan during Operation Phase

Sl. No.


Per Sample Cost

(in INR) (A)

No. of Sample

(B)

Total Cost (in INR)

(D) (A*B=C)

1. Water pH, Conductivity, TSS, TDS, Heavy Metals, BOD, COD, Oil & Grease, Total Petroleum, Hydrocarbons (TPH) and Petroleum Aromatic Hydrocarbons (PAHs).

8000 30 2,40,000

2. Sediments Ph Texture, Organic matter, Nitrogen, Phosphorous, Oil & Grease, Heavy Metal Concentration, Total Petroleum, Hydrocarbons (TPH) and Petroleum Aromatic Hydrocarbons (PAHs).

8000 30 2,40,000

3. Ecological Phytoplanktons, Zooplanktons, Benthos and Chlorophyll estimation.

9000 30 2,70,000

Total 7,50,000

An amount of approximately INR 9.50 lakh will be spent for the compliance of environmental quality monitoring plan during drilling/ Installation phase. INR 7.50 lakh will be spent annually during operation phase of the project.

66

AADDDDIITTIIOONNAALL SSTTUUDDIIEESS



1. ADDITIONAL STUDIES

6.1 INTRODUCTION

Adani Welspun Exploration Limited (AWEL) plans to develop the B-9 Cluster Field which is a discovered small field (DSF) by Oil and Natural Gas Corporation (ONGC). Its developmental activities will be including drilling of wells and installation of offshore well-head platform facilities to produce natural gas and crude oil and lying of subsea pipelines. The cluster field comprises of three (3) DSF offshore field namely B-9, B-7 and BRC.

The type of rig used during the drilling phase is planned to commence drilling using a self-contained Mobile Offshore Drilling Unit (MODU), i.e., a Jack-Up Rig capable of performing shallow water drilling activities. Risk assessment includes the identification of risks involved in the drilling process and the associated activities in the drilling program, and the assessment of probability of certain consequences. This chapter highlights the studies of the risk assessment, disaster management plan and emergency action plan in the following chapters.

Salient Features of the Project

The overall project activity consists of drilling of twelve (12) wells and four (4) well head platforms, subsea pipeline of approximately 130 km in length (50 Km intra-field pipeline and 80 Km export pipeline joining B-9-1 platform and C-24RP).

The platforms are planned to be minimum facilities well-head platforms comprising of well-head, production & test manifold, well-head control panel, scrapper launcher, instrument gas system, local power generation (solar or other), heli-deck, jib-crane, fiscal metering, real-time production data transfer to Director General of Hydrocarbon (DGH) through satellite communication, etc.

The development for B-9 field will include 2 well head platforms, while B-7 and BRC will include installation of 1 well head platform each, inter-field sub-sea pipelines and hooking up at B-9 area. The BRC platform is also envisaged to include facilities to handle, stabilise, store and export oil.

6.2 RISK ASSESSMENT

The risk assessment (RA) study is aimed at identifying the potential sources which pose risks of a hazard outbreak, determining the probability of such hazard occurrences and their consequences. The risk assessment exercise mitigates the severity of any accident and facilitates preparation of an effective emergency action plan (EAP) or disaster management plan (DMP). Hydrocarbon operations are generally hazardous in nature due to the intrinsic chemical properties of hydrocarbons, temperature, pressure or a combination of them. The hazards associated with hydrocarbon operations are fire, explosion, release of chemicals or a combination of these hazards. RA study helps to improve upon the integrity, reliability and safety of hydrocarbon operations. The RA studies are based on the Quantitative Risk Assessment (QRA) Analysis.

66



6.2.1 Risk Analysis

The most important step is to recognize all the possible hazards and their associated risks in the site and its surroundings to ensure the safety and consistency of the drilling operations. Risk analysis is the tool used to determine the consequence of operational failure in drilling and related activities.

6.2.2 Identification of Hazards in Offshore Oil and Gas Field Development

Considering the applicability of different risks aspects to be undertaken in the proposed project, various hazards associated with extraction of hydrocarbon in offshore productions are as follows:

• Blowouts • Collisions • Helicopter crash • Presence of H2S • Process leaks • Process and Non-Process fires/explosions

In addition, it is understood that the causative factors and mitigation measures for such events will be adequately taken care of through existing safety management procedures and practices of AWEL.

The above risks and hazard have been evaluated based on the likelihood of occurrence and the magnitude of consequences. The significance of the risk is expressed as the product of likelihood and the consequence of the risk event which is expressed as given below:

Significance = Likelihood x Consequence

Figure 6.1 below illustrates the risk matrix with all possible product results for the four likelihood and consequence categories and the Figure 6.2 assigns risk significance criteria in three regions that identify the limit of risk acceptability according to the policy and the strategic objectives of the proponent. Depending on the position of the intersection of a column with a row in the risk matrix, hazard prone activities have been classified as low, medium and high, thereby qualifying for a set of risk reduction / mitigation strategies.

Severity of Consequence

Likelihood of Occurrence O A B C D E

1 Continuous Improvement 2 Risk Reduction Measures 3 4 Intolerable Risk 5

Figure 6.1: Risk Matrix and Acceptability Criteria



Risk Criteria Definition

Low (Continuous Improvement)

The level of risk is broadly acceptable and no Specific control measures are required

Medium (Risk Reduction Measures)

The level of risk can be tolerable only once a structured review of risk reduction measures has been carried out

High (Intolerable Risk)

The level of risk is not acceptable and risk control measures are required to move the risk figure to the previous regions

Figure 6.2: Risk Categories and Significance Criteria

6.2.3 Major Hazards

a. Hazards due to Installation of Pipelines and Platform Installation of pipelines - During the pipeline installation, the possible hazards are-

• Dropped and dragged anchor chain from pipe lay vessel, • Vessel collision during laying leading to dropped object, etc. • Loss of tension drop of pipe end, etc. • Damage during trenching, gravel dumping, installation of protection cover, etc. • Damage during crossing construction.

Platform Operations - During the platform operations, the possible hazards are- • Drop of objects into the sea.

b. Oil Spill

Minor Oil Spill - During the well testing operation, there exists a possibility of hydrocarbon gases / oil getting released due to some unavoidable incidents. Once the flow of oil / gas from well is stopped, then on-site access for clean-up is possible. If flow from well cannot be stopped, a blowout situation exists. Major Oil Spill - Significant hydrocarbon inventories will not be maintained at the rig. A major spill can, therefore, only arise as a result of an uncontrolled flow from a well i.e. blowout. Provided that ignition does not take place and the well head is not obstructed the well can be shut in at the wellhead. If ignition occurs or other damage prevents access to the wellhead then a blowout situation exists, and appropriate measures must be implemented.

c. Blowout

Blowout means uncontrolled violent escape of hydrocarbon fluids (gas with associated water, gas with condensate and gas with oil) from a well. The oil and condensate concentrations are very small and gas coming out from reservoir is already stripped out of both and saturated with water. Its combustion characteristics are unlikely to be affected by oil.

Blowout followed by ignition which prevents access to the wellhead is a major hazard. The various contributors to blowout are:

Primary • Failure to keep the hole full. • Mud weight too low.



• Swabbing during trips. • Lost circulation. • Failure of differential fill-up equipment.

Secondary • Failure to detect and control a kick as quickly as possible. • Mechanical failure of Blowout Preventer (BOP). • Failure to test BOP equipment properly. • Damage to or failure of wellhead equipment. • Failure of casing. • Failure of formation or cement bond around casing.

Blow Out Consequences and Effects: A blowout incident can take a variety of different forms, ranging from a minor leak which can be stopped within minutes, to a major release which continues out of control for days or even months. The consequences of a blowout event will to a large extent depend on how the blowout scenario evolves and the following possible scenarios are likely:

• Release of high pressure inflammable and explosive gas. This may have deleterious effect on the coastal traffic

• Ignition of the flammable gas released resulting in a jet fire, pool fire or an explosion

Ignition of released gas can possibly result in considerable harm, with historical data showing 40 % blowout such incidences leading to more than significant damage to the drilling ship / platform (WOAD database) and resulting in associated fatalities amongst drilling crew and support personnel present on the ship / platform. Also, ignition has been recorded in about 30% of the blowout cases on an average (SINTEF offshore blowout database). However, on positive side, with improvement of offshore drilling, production and product transfer- transport technology, number of offshore blowouts occurring has significantly gone down in the last decade. Hazards in the platforms will be mostly from HC gas leakage and also from chemical spillage (methanol or others). The leakage from process equipment (flange connections/instrument tapings or catastrophic equipment flange failures) can occur. The rate of leakage will depend upon system pressure, depth and opening size. Risk Ranking for Blowouts

Likelihood Ranking – B; Consequence Ranking – 5; Risk Ranking –5B (High)

If the hydrostatic head exerted by the column of drilling fluid can drop below the formation pressure then formation fluids will enter the wellbore (this is known as a kick) and a potential blowout situation has developed. Fast and efficient action by operating personnel in recognizing the above situations and taking precautionary measure can avert a blowout.

d. Collisions Involving Drill Ship (MODU)

A collision situation is considered for the risk assessment for the impacts on “Well Unit” by heavy falling objects from other drill ships or other marine vessels working nearby or passing by it.

The following possibilities have been taken into consideration:



• Visiting support vessels which approaches the MODU under their own power and including supply vessels, standby vessels accidently release some objects and it hits the well.

Consequences and Effects The analysis of collision consequences is generally based on the principle of conservation of energy. The impact of a full-on collision may however be more severe and may lead to damage to the well and may lead to a rupture or leak in the riser resulting in a process leak or a blowout.

Risk Ranking for Vessel Collision

Likelihood Ranking – C; Consequence Ranking – 3; Risk Ranking - 3C (Medium)

e. Helicopter Crashes

The journey to-and-fro offshore rig has historically been one of the main reasons for accidental death or injury to many offshore workers. For the AWEL drilling activities, crew transport to-and-fro the MODU shall be by helicopter, due to its speed, convenience and good operability under rough weather conditions. Several approaches exist to analyze probability of helicopter crash risks.

A more reasonable approach involves the use of individual risk approach as a product of 3 components:

• Frequency of helicopter accidents per flight • Proportion of accidents which involve fatalities • Proportion of personnel on board in fatal accidents who become fatalities.

Consequences and Effects

Helicopter crashes involved with offshore oil & gas exploration and production have happened in the past, especially in the North Sea offshore operations in Europe, with some resulting in fatalities or injuries to crew members. In addition to the risk posed to the helicopter occupants, accidents involving helicopters can also cause damage to the drill ship itself by way of crashing into the ship during take-off or landing or by an accident when the helicopter is on the helideck. However, the consequence of such risk may be considered to be small compared to the other risks sources on the MODU.

Risk Ranking for Helicopter Crash

Likelihood Ranking – B; Consequence Ranking – 3; Risk Ranking - 3B (Medium)

6.2.4 Hazards - Nature and sensitivity of impact zones

Subsea Pipeline:

1) Natural hazards - Landslides

The generation of landslides that could potentially affect the pipeline integrity has been qualitatively evaluated at the outset of the project for the entire pipeline route. It was concluded that the pipelines are not threatened by landslide. The occurrence of a landslide is due to the coexistence of various conditions such as:

i) Thick layers of very soft sediments lying on steep slopes ii) Slope angles able to trigger the development of soil instability



iii) Triggering mechanisms causing the landslides (e.g. seismic loads, wave loads, rapid accumulation of soft sediments)

No such conditions have been found along the pipeline routes. In addition the proposed pipeline support system is designed after conducting on-bottom stability tests and maximum free span lengths to take care of the subsea soil erosion (if any) and regular inspection of pipeline route will caution of any likely damage.

2) Natural hazards - Extreme Storm

The following met ocean design conditions are used for the detailed design of the system

i) Seasonal and whole year directional extremes of wind, waves and currents ii) Directional significant wave height

iii) Wave and current climate for fatigue analysis

Air temperature extremes and climate at landfall locations

i) Persistence of storm and calm conditions for onsite operations ii) Variability of the sea level

iii) Hydrological sea water parameters (temperature, salinity and density)

Arabian sea is known for rough weather; since the production operational system and Subsea pipeline will be near the sea bottom, it is unlikely to be affected much with rough weather.

3) Heavy Impact and Damage to pipeline due to dropping of heavy objects

A situation is considered for the risk assessment for the impacts on ―Subsea Pipeline‖ by heavy falling objects from other drill ships or other marine vessels working nearby or passing by it. The following possibilities have been taken into consideration:

i) Vessels which passes through the pipeline route may accidently release some heavy objects/ anchors and it hits the Pipeline.

Consequences and Effects

The analysis of consequences is generally based on the principle of conservation of energy. The impact of a complete contact with the object may however be more severe and may lead to damage to the pipeline such as rupture or leak from the pipeline resulting in a process leak.

Risk Ranking Likelihood Ranking - C Consequence Ranking - 3 Risk Ranking - 3C (Medium)

Failure Scenarios (Likely)

Subsea Pipeline

Subsea pipeline will be laid at sea surface. The sea water will exert pressure on the line which can be high. Any opening in the operating pipe line (due to any damage or any other cause) will result in gas leakage. Leaking gas will disperse (to some extent) due to wave motion and come to surface in a wide area. The area of dispersion will depend upon depth of pipeline, current / sea roughness, weather etc. However, for modeling (60%) part of the leakage have been considered as concentrated at one place and catch fire, The rate of leakage will depend



upon pipe line pressure, depth and opening size. Considering these key parameters four scenarios /cases are envisaged.

6.3 Control Measures for Major Identified Hazards

The preventive control measures to prevent/avoid occurrence of hazardous stance are given below:

a) Pipeline and Platform Installations-

i. Limit lifting to certain zones, sectors, areas- • This reduces/eliminates the frequency effectively. • Often used when lifting heavy objects as BOP on rigs. • The rig is withdrawn from the area when lowering the BOP. • For pipe loading onboard a lay-barge only the crane on the side furthest away

should be used when laying parallel to or crossing existing line. ii. Limit the type of objects lifted in certain zones-

• For example, only the cranes away from the vulnerable area may lift heavy objects.

• Or to not allow pipe loading onboard bay barge within platform safety zone. • Reduces/eliminates the risk efficiently.

iii. Introduce safety distance- • The activity is either planned performed in a safe distance away from the

pipeline or vice versa (e.g. anchor handling). iv. Increase the protection-

• Increased protection will reduce the damage to the pipeline. Increased protection may be obtained by a variety of solutions. It should be noted that some solutions might introduce a very high risk to the pipeline during installation, in addition also introduce scouring problem during the lifetime.

b) Blowout

Precaution against Blowout

The following control equipment for drilling mud system shall be installed and kept in use during drilling operations to prevent the blowout:

i. A tank level indicator registering increase or reduction in the drilling mud volume and shall include a visual and audio –warning device near the driller stand.

ii. A device to accurately measure the volume of mud required to keep the well filled at all times.

iii. A gas detector or explosive meter at the primary shale shaker and connected to audible or visual alarm near the driller stand.

iv. A device to ensure filling of well with mud when the string is being pulled out. v. A control device near driller stand to close the mud pump when well kicks. vi. Blowout prevention drill shall be carried out once every week near the well during

drilling. vii. Suitable control valves shall be kept available near the well which can be used in case

of emergency to control the well. viii. When running in or pulling out tubing, gate valve and tubing hanger shall be pre-

assembled and kept readily available at the well.



Precaution after Blowout

On appearance of any sign indicating the blowout of well, all persons, other than those whose presence is deemed necessary for controlling blowout, shall be withdrawn from the location.

While controlling of blowout is in progress, the following precautions shall be taken:

i. A competent person shall be present on the spot throughout. ii. An area within the 500 meters of the well on the down wind direction shall be

demarcated as danger zone. iii. All electrical installations shall be de-energized. iv. Approved safety lamps or torches shall only be used within the danger zone. v. No naked light or vehicular traffic shall be permitted within the danger zone. vi. A competent person shall ascertain the condition of ventilation and presence of gases

with an approved instrument as far as safety of persons is concerned. vii. These shall be available at or near the place, two approved type of self-contained

breathing apparatus or any other breathing apparatus of approved type for use in an emergency.

viii. Adequate firefighting equipment shall be kept readily available for immediate use.

c) Vessel Collisions

A Vessel Management Plan will be formulated and implemented to reduce collision risk, both vessel–vessel and MODU–vessel and shall address the following:

i. Mandatory 500 m safety zone around well location ii. Operational restrictions on visiting vessels in bad weather iii. Defined vessel no-go areas within safety zone; and agreed approach procedures to rig by

supply and safety vessels

Evacuation plan in case of vessel collisions –

i. Launching the lifeboats by embarkation and lowering. ii. Deploying the chutes and rafts, going down with the help of chutes followed by

transferring the people from platform to rafts. iii. Attach the towing line of rafts to lifeboats and/or rescue boats. iv. Sail away from abandoned vessel. v. Wait for rescue. vi. Further rescue depends on availability of Search and Rescue (SAR) appliances on the

location of evacuation zone, like MRCC boats, helicopters or passing (re-routed) ships.

d) Helicopter Crash

i. Air worthiness of helicopter to be checked by competent authority or before helicopter is hired.

ii. AWEL should ensure that the pilot/pilots who will be operating have got appropriate training on similar craft.

iii. Effective arrangements for coordination would be developed with air traffic control room at Base port, as also in the MODU.

iv. Helicopter operations to be restricted during night time and during bad weather conditions.

v. All employees who are supposed to travel on helicopters would be receiving basic training on rescue and survival techniques in the case of a helicopter crash at sea.



LDAR program

Hydrocarbon industry in general and Natural gas producing and processing facility is highly hazardous in nature due to the inflammable/explosive nature and also toxic nature (if H2S is there in Natural gas). Some of the chemicals used are also hazardous. The proposed project is using pipelines, vessels, compressors, pumps, valves and other fittings in the transfer and processing of gas/fluid from offshore wells to the terminal. To reduce fugitive emissions proper Leak Detection & Repair (LDAR) program is required.

The proposed LDAR program is as follows:

i. Identification of sources: Valves, pipes, joints, pump and compressors seals, flanges etc.

ii. Monitoring of Gas/Volatile Organic Compound (VOC) is to be carried out regularly through permanent Gas monitors at strategic locations and also portable gas detector. Monitoring frequency should be once in a quarter is required.

iii. Focus should be for prevention of fugitive emissions by having preventive maintenance of pumps, valves, pipelines etc. A preventive maintenance schedule should be prepared and it should be strictly adhered to.

iv. When monitoring results indicate Gas/VOC above permissible limit repairing should be done immediately. The repair should be conducted in such a way that there is no fugitive emission from the particular component.

Fugitive Emission

The following guidelines for fugitive emissions should be strictly followed:

ix. Fugitive emissions over and around vessels and other machineries transfer areas etc. should be monitored regularly.

x. Enclosures to chemical storage area should be provided. xi. Vapor balancing, nitrogen blanketing, isolated tanks etc., should be provided. Special

care will be taken for odorous chemicals.

6.4 DISASTER MANAGEMENT PLAN AND EMERGENCY ACTION PLAN

For meeting the emergencies caused by major accidents, planning of response strategies are termed as Disaster Management Plans (DMPs). It shall cater to the worst-case scenarios with reference to specific cases like oil/chemical spillage, fire, explosion, natural calamities like tsunamis, earthquakes, cyclones, etc. It shall include early detection of emergency commands and coordination of response organizations along with trained personnel, availability of required resources, emergency response actions, effective communication facilities and training facilities to the personnel. DMPs cannot be considered in isolation or act as a substitute for maintaining good safety standards in a plant. The best way to protect against major accidents occurrence is by maintaining very high levels of safety standards.

Generally, the following five (5) phases are involved in an emergency:

i. Discovery and Notification: An event with an imminent threat of turning into an accident must first be discovered and the discoverer quickly notifies the same to the plant safety officer and also Duty Officer on shore.

ii. Evaluation and Accident Control Initiation: Based on the evaluation of available information, the safety officer makes a rapid assessment of the severity of the likely accident and initiates the best course of action.



iii. Containment and Counter Measures: Action is first taken to contain and control the accident by eliminating the causes which may lead to the spread of accident. Measures are also taken to minimize the damage to personnel, property and environment.

iv. Clean-up and Disposal: After the accident is effectively contained and controlled, the clean-up of the site of the accident and safe disposal of waste generated due to the accident are undertaken.

v. Documentation: All aspects of accidents, including the way it started and progressed as well as the steps taken to contain and the extent of the damage and injury, must be documented for subsequent analysis of accident for prevention in future, damage estimation, insurance recovery and compensation payment. It may be noted that some aspects of documentation, such as, photographs of the site of accident and main objects involved in the accident, survey for damage estimation, etc. may have to be carried out before the cleanup and disposal phase. However, the effort in all cases is to recommence the production as soon as possible.

6.4.1 Emergency Classification

Severity of accident and its likely impact area will determine the level of emergency and the DMP required for appropriate handling of an emergency. Emergency levels and the action needed for each level are indicated below:

i. Level 1- Emergency: A local accident with a likely impact only to immediate surroundings of accident site, such as, local fires and limited release of inflammable material. The impact distance may not be more than 15 m from the site of primary accident and may require evacuation of the drilling area where accident occurred and utmost the adjacent drilling rig.

ii. Level 2- Emergency: A major accident with potential threats to life and property up to 500 m distance requiring the evacuation of all personnel from the threatened area except the emergency response personnel. Large fires and release of large quantities of inflammable materials may belong Level-2 emergency.

iii. Level 3- Emergency: An accident involving a very serious hazard and with likely impact area is extending beyond the operational area limit of the exploration rig, such as, major fire, large release of inflammable material and big explosion. Major fires will usually have the triggering effect resulting in the propagation of explosion. In a Level-3 emergency, evacuation populations near the development well periphery (if near coast) and alert the fishing and other vessels operating in nearby areas.

On-site Disaster Management Plan (DMP) will meet the hazards created due to all Level-1 emergencies and most of the Level-2 emergencies. In addition to on-site DMP, off-site DMP may also have to be put into operation for some Level-2 and all Level-3 emergencies.

6.4.2 Emergency Action Plan

The emergency action plan for the proposed project is given below:

6.4.2.1 Instrumentation and Safety System

The main features of instrumentation on each well-head comprises of Platform Monitoring and Safety systems installed in the E&I Room comprising of the following:



i. Programmable Logic Controller (PLC) based Remote Telemetry Unit (RTU) for platform Monitoring

ii. PLC based Fire & Gas Detection System (FGS)

Shutdown Panel (SDP) for topside emergency shutdown (Subsurface Safety Valve (SSSV) - hydraulic, SSV/ topside shutdown valves – Pneumatic). Flow Meter (Orifice Plate) at each Flow Arm for Real Time Data measurement. Pressure and temperature measurement as indicated in P&ID. All the Process Field Instruments installed for status Monitoring of the platform to be connected to Platform Remote Telemetry Unit (RTU) via Field Junction Boxes. All shutdown related Process Field Instruments & Valves i.e. SSV, SSSV, Shutdown Valves, LL/ HH Pneumatic Pressure Switches to be connected to the Platform Shutdown panel (SDP) which will initiate platform shutdown during emergency. Fire & Gas Devices to be installed at Field to ensure safe operation of un-manned wellhead platform. These Fire & Gas Devices at Field to be connected to Fire & Gas Detection System (FGS) via Field Junction Boxes.

a. Remote Telemetry Unit (RTU)

RTU to be microprocessor based and to be composed of standard hardware and system software, which can be configured to meet the stated requirements. RTU shall have redundant Processor, Power supply and Communication modules, Simplex I/O Modules. The scan time of the PLC to be 250 milli-seconds or better. The Programmable logic controller (PLC) to be “Fault avoidant” and to be based on high-reliability, high-availability programmable electronic systems.

b. Fire and Gas Detection System (FGS)

F&G PLC to be microprocessor based and to be composed of standard hardware and system software, which can be configured to meet the stated requirements. F&G PLC shall have redundant Processor, Power supply, I/O Modules and Communication modules. FGS system to be SIL-3 Compliant with Technical Inspection Association (TUV) safety certificates. The scan time of the PLC to be 250 milli-seconds or better. The PLC to be “Fault avoidant” and to be based on high-reliability, high-availability programmable electronic systems.

Manual Emergency Shut-Down (ESD) loop is also installed around the platform to initiate a Shutdown in event of fire. Once the Operator or any personnel on the platform have a visual of the fire, he shall press the manual ESD button strategically located around the around the platform. Pressure transmitter located inside SDP will monitor the status of the Manual ESD loop and provide shutdown via low pressure set point.

Hydrocarbon Gas detectors to be installed at various locations of the Process facilities to cover entire platform and to detect the Gas leak in process facility.

These gas detectors to be hardwired to F&G PLC and will provide an alarm or shutdown the platform in event of gas detection. 2oo3 voting philosophy to be applied for Hydrocarbon Gas detection and 1oo2 voting philosophy to be applied for Hydrogen Gas detection. Smoke detector to be installed inside E&I Room & Battery room.

c. Shut Down Panel (SDP)/ Well-Head Control Panel (WHCP)

Shutdown Panel (SDP) for topside emergency shutdown (Subsurface Safety Valves (SSSV) - hydraulic, Surface Safety Valves (SSV)/ topside shutdown valves – Pneumatic) to be provided. The panel will be fitted with Gas driven hydraulic pumps to provide the hydraulic



power required to hold all SSSVs in the open position under normal conditions and to close these valves in case of a process upset or emergency. Additionally, the SDP shall also provide the Gas pressure to operate the SSV and the actuated shutdown valves.

d. High Integrity Pressure Protection System (HIPPS)

HIPPS PLC to be microprocessor based and to be composed of standard hardware and system software, which can be configured to meet the stated requirements. HIPPS PLC shall have redundant Processor, Power supply, I/O Modules and Communication modules. The Complete HIPPS system to be SIL-3 Compliant with TUV safety certificates. The scan time of the PLC to be 250 milli-seconds or better. The PLC to be “Fault avoidant” and to be based on high-reliability, high-availability programmable electronic systems.

The basic function of the HIPPS system is to detect high-high pressure in the Production header and to reliably & quickly isolate the source of the high pressure through closure of Primary and Secondary shutdown valves and to send signals to the Remote Terminal Unit (RTU) & SDP. HIPPS System shall conform to Safety Requirements Specification according to IEC 61511/61508.

The system shall employ three independent channels capable of receiving individual 4-20mA analog signals from field pressure transmitters. The independent channels to be processed and voted via 2oo3 architecture. The 2oo3 design shall allow each individual channel to be tested and maintained online without bypassing and to be hot swappable. The three HIPPS pressure transmitters are managed and monitored in 2oo3 voting logic, so in case of two HH (high-high pressure) threshold exceeded, the HIPPS system close both Primary and Secondary shutdown valve. HIPPS System to be connected to the RTU via a serial link Modbus for transmitting the signal pertaining to alarms and statuses. All the instruments installed on the topsides to be as a minimum suitable for use in a Zone 2 Group IIA T3 environment.

e. Environmental Protection

Instrument equipment will have minimum degree of protection IP-65 and paint finish will be proven to be suitable for long term service in an offshore tropical marine environment.

f. Power Supply

Components of power supply system to be of highest available quality for reliability and long service life. Power supplies for all transmitters, controllers, signal converters, electric system and components in shutdown system to be supplied from uninterruptible power supplies. Power distribution to each consumer to be through proper, independent switch and fuse. Protective fuses to be of indicating cartridge type mounted in fuse holders. In general, the following Power Supplies to be used for instrumentation and Control: 24V DC +5% / -10%, with Floating Earth/Unearthed except for RTU.

g. Instrument Air / Gas

Instrument air supply shall conform to ISA S7.0.01 “Quality Standard for Instrument Air”. Each pneumatic instrument supply to be provided with independent filter regulator. For pneumatic instruments, dry instrument gas/ air supply to be as follows:

• 5.5 Kg/cm2 (Minimum) • 7.5 Kg/cm2 (Normal) • 10.5 Kg/cm2 (Maximum)



h. Hydraulic Supply

Hydraulic fluid to be used on Wellhead as an actuating medium for SSSV. Hydraulic supply to be derived from Shut Down Panel (SDP). The primary objective of the SDP is to supply the required hydraulic fluid to the wellhead Christmas tree valves SSSV. SDP to be provided with the following hydraulic pressure headers:

• Medium Pressure (MP) header: 350 Kg/Cm2 (Design) • Consumer for MP: SSSV

6.4.2.2 Telecommunication System

To facilitate the platform for Voice, Data & Security surveillance the below Telecommunication system are proposed for the project as below:

a. Very Small Aperture Terminals (VSAT) SYSTEM - (Voice and Data Communication) b. CCTV SYSTEM - (Security Surveillance)

Over all Telecom scope consists of providing above listed Telecommunication systems and subsystems located at wellhead platforms.

CCTV System

Unmanned Well head platform (WHP) will be equipped with CCTV camera for surveillance. The Camera images to be transmitted to the VSAT Telecom Facilitator/operator through VSAT system.

6.5 HEALTH, SAFETY AND ENVIRONMENT (HSE)

Platform to be provided with Fire and Gas detection system, safety of navigation aids, air craft warning light, emergency shutdown stations etc. All emergency and shutdown system to be designed fail safe. External walls of Temporary Shelter shall have fire rating H60 and blast rating 0.2bar. Cold vent tip to be located based on radiation limit for ignited vent (4.7 kW/m2) and flammable gases concentration (50% LFL) at platform deck. HIPPS system shall conform to Safety Requirements Specification and Process Safety Time according to IEC 61511 and IEC 61508 requirements.

All Safety Instrument Systems to be SIL verified and validated. Proof test intervals, Mean Time to restore etc. to be discussed with and approved by company before SIL verification. Equipment noise shall not exceed 85 db (A) at 1m. Human Factors to be considered in accessibility, valve handling, emergency switches / buttons, local indicators etc. Platform model review to be performed using relevant and specific human factors checklist. All design safety requirements in applicable legislations/regulations to be implemented. EPC contractor shall implement recommendation in Environment Clearance and Environmental Impact Assessment performed by others.

Life Saving Appliances (LSA) / Fire Safety Appliances (FSA)

Each platform to be provided with minimum following LSA / FSA.

• 10 kg DCP extinguishers • 5kg CO2 extinguishers • Wheeled 50 L AFFF – Cellar deck & Helideck • Wheeled 50 kg DCP - Cellar deck



• Helideck to be provided with portable fire extinguishers and crash rescue kit as per DGCA requirements

• Life Raft (2 Nos.) & Scramble net (2 nos.) – 10 Personnel capacity • Life ring buoys – One at each side of all levels and boat landing • Life jackets in cabinet and temporary shelter • Wind Sock • Stretcher, first-aid kit etc. • Self-contained eye wash near chemical injection • Life Saving Appliances shall comply with IMO LSA Code and Fire Extinguishers to

be UL/FM listed • Fire extinguisher distribution shall meet NFPA 1 requirements

Emergency Evacuation In the event of hydrocarbon leak or fire, personnel on-board will evacuate the platform via boat landing on to a standby boat. Alternate means of evacuation will be life raft. In the event of bad weather/storm, when evacuation is not possible, personnel will shelter in temporary shelter.

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2. PROJECT BENEFITS

7.1 PROJECT BENEFITS

As per a report published by FICCI, India is the fifth largest energy consumer in the world. While the world consumes 12000 million tonnes of oil equivalent (mtoe) of energy resources, India consumes 4.4% of the world total (524.2 mtoe).

Of the total primary energy consumption basket, oil and gas constitute 45% share in the total energy basket mix. About 78 per cent of India’s petroleum consumption is met from imports (mostly of crude oil), while about 25% of natural gas (including LNG) consumption comes from imports. It is estimated that in the coming years, the import dependency for crude oil alone would reach above 90% level.

Thus, Development of existing oil reserves has become a necessity to bridge the rising demand-supply gap, reduce import dependency and make ourselves resilient to the external factors of economic and political disruptions in the sourcing nations.

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1. ENVIRONMENTAL MANAGEMENT PLAN

8.1 STRUCTURE OF EMP

Environmental Management Plan (EMP) is the key to ensure a safe and clean environment. The desired results from the environmental mitigation measures proposed in the project may not be obtained without a management plan to assure its proper implementation and function. The EMP envisages the plans for the proper implementation of mitigation measures to reduce the adverse impacts arising out of the project activities. EMP has been prepared addressing the issues like:

• Pollution control/mitigation measures for abatement of the undesirable impacts caused during the drilling and installation and operation stages.

• Details of management plans.

• Post project environmental monitoring programme to be undertaken (Chapter 5).

• Expenditures for environmental protection measures and budget for EMP.

8.2 PROPOSED ENVIRONMENTAL MITIGATION MEASURES

The details of the impacts resulting due to different activities during drilling and operation phases are given in Chapter 4. Based on these mitigation measures Environmental Management Plan (EMP) is drafted. The environmental mitigation measures for construction and operation phases are briefly listed in Table 8.1.

Table 8.1: Proposed Environmental Mitigation Measures

S. No.


Drilling and Installation Phase 1. Marine

Water Quality

• Displacement of sea-bed sediments may lead to anoxic intertidal and offshore mud, leading to the local chemical changes in water quality

• Water quality may be affected by the solid/liquid discharge and accidental spillage of chemicals

• The sewage shall be treated on-board of the rig according to the MARPOL Regulations. Residual chlorine of the treated sewage shall not exceed 1mg/L before disposal.

2. Marine Sediment

• Activities like deployment of rigs and other sub-sea infrastructure may cause local and temporary disturbance to the sea-bed

• The layout of the subsea infrastructure shall be designed to avoid sea bed features considered to be geo-hazards.

8



S. No.


3. Marine Ecology

• Adverse impact on marine life due to drilling activity, noise generation, effluent discharge.

• All precautionary measures shall be adopted to minimize disturbance to the marine animals due to deployment and operations of offshore wells.

4. Air Environment

• NOx, PM₁₀, and SOx emissions from venting, flaring and D.G. Sets.

• Good operational controls and high level of monitoring shall be built into the design operations.

• Regular maintenance of engines and DG sets shall be ensured.

• The existing and proposed DG sets shall comply with the applicable emission norms.

5. Noise Environment

• Noise and Vibrations from the heavy machineries - large power generation units, diesel engines, fluid pumps and mud pumps, equipment and transportation vehicles

• Mobile noise sources such as rig, and vessels shall be re-routed to avoid disturbances.

• Avoid loud, sudden noises, wherever possible. Integral noise shielding shall be used where practicable and applicable


• Respiratory disease due to inhalation of dust

• Auditory ailment due to noise


• The use of personal protective equipment like ear muffs and dust mask shall be made stringent

• Water sprinkling system for fugitive dust generating areas

• Safety training to workers • Regular health check-ups for

workers/ employees Operation Phase 1. Marine

Water • The water quality of the

project site may get affected due to accidental spillage of chemicals/oil/lubricants from the routine operational activities

• Usage of only low toxicity chemicals must be ensured on-board of the rig and transportation vessels

• Adequate well management shall be ensured during well completion activities to minimize produced water production

2. Marine Sediment

• Sediment quality is less likely to be affected due to operational discharges and accidental spillage of fuel/chemical/lubricant




S. No.


during the routine operational activities

3. Marine Ecology

• Sub-sea infrastructure shall act as a physical hindrance to the marine organisms leading to direct habitat loss

• The operational activities are also likely to have an impact on the benthos in the benthic zone

• All precautionary measures shall be adopted to minimize disturbance to the marine animals due to deployment and operations of offshore wells

4. Air • Air emissions may result from gas flaring activities during the well testing only (1-2 days).

• Regular maintenance of the transportation vessels

• Regular ambient air quality monitoring must be carried out.

5. Noise and Vibration

• Noise is likely to be generated during the operation phase due to the operation of rigs, generators, etc.

• Rubber padding/noise isolators shall be provided at equipment/machineries

• Regular maintenance of all equipment and transportation vessels shall be ensured



• Strict enforcement of PPEs on workers/ employees

• Safety training to workers • Cordoning of hazardous areas

as ‘No Smoking Zone’ • Bi-annual or annual health

check-up camps for workers/ employees

8.3 ENVIRONMENTAL MANAGEMENT PLAN

The Environmental Management Plan is prepared to facilitate the field level implementations. This plan needs to be well implemented during drilling and installation as well as operation phases of the project. The mitigation management matrix is given in Table 8.2, wherein the impacts of the project activities are mentioned along with the actions required for effective environmental management.



Table 8.2: Environmental Management Plan - Mitigation Management Matrix (during Drilling Phase)

Hazards and Effects Proposed Mitigation Required Action

Wastewater and Effluent Management

• Sewage will be treated on-board the rig. Residual chlorine of the treated sewage will not exceed 1mg/L before disposal.

• Drilling, wash water and oily water will be treated to conform to limits notified as per MARPOL Regulations, before disposal into sea. The treated effluent will be monitored regularly.

• WBM or SOBM (to be used in special case only) will be disposed off as per G.S.R. 546 (E); dated 30/08/05,

• Thoroughly washed the drill cuttings separated from WBM and unusable portion of WBM having toxicity of 96 hr LC50 Value> 30,000 mg/L will be discharged offshore into sea intermittently, at an average rate of 50 bbl/hr/well from a platform so as to have proper dilution and dispersion without any adverse impact on marine environment.

• Unusable portion of SOBM will not be discharged into sea and shall be bought to onshore for treatment and disposal in an impervious waste disposal pit.

• Treatment of sewage will be ensured as per MARPOL regulations.

• It will be ensured that oil content of the effluent without dilution will not exceed 40 ppm.

• In special case of use of SOBM, low toxicity OBM should have aromatic content <1 % will be used.

• It will be ensured that the toxicity of the chemical additive used in WBM/ SOBM is biodegradable and have toxicity of 96 hr LC50 Value > 30,000 mg/L as per mysid toxicity or toxicity test conducted on locally available sensitive sea species.

• It will be ensured that Oil drilling operators record the daily discharge of drilling fluid, monitor the effluent quality and submit the compliance report once in every six months to MoEF.

Fuels, Lubricants and Chemicals Management

• Oil Spill Contingency Plan (OSCP)-(as given in section 8.3.2) will be implemented to handle all major, moderate and minor spills.

• Suitable delivery vessels will be used. • Oil drip pans will be used wherever there is

significant potential for leakage.

• Implementation of OSCP will be ensured. • Casing should be ensured to prevent leakage. • Delivery vessels will be checked for their

suitability & ensured that they meet safety requirements.

• Oil drip pans will be made available.




• All spills/leaks will be reported and cleaned up immediately.

Noise • Regular maintenance of all equipments and pumps will be ensured.

• Good working practices will be implemented to minimize noise.

• Noise mitigation measures such as acoustic enclosure will be provided to operating machines and engines will be provided with mufflers.

• Proper acoustic enclosure will be provided at the drilling site.

• Personal protective equipment will be provided to the workers exposed to prolonged noise levels.

• Equipment log books will be maintained. • It will be ensured that no machinery is working

when not in use. • Enclosures will be ensured around the noise • generating sources where the noise levels exceed

the permissible admissible limits. • Generator sets will be installed in compliance with

the MoEF norms. • Installation of acoustic enclosure at drilling site

will be ensured as per the norms notified by MoEF.

• Sufficient quantity of Personal Protective Equipment will be made available.

Air Emissions • All equipments will be operated within specified design parameters.

• High efficiency generator sets will be provided with adequate stack height and modern emission control equipments. Emission can be minimized further by use of low sulfur diesel (i.e. present sulphur content of HSD utilized is 50 ppm).

• Measures will be taken to minimize emissions during gas flaring.

• Follow up of preventive and scheduled maintenance of all the equipments as per the procedures given by OEM will be ensured.

• It will be ensured that stacks/vents height will be provided as per CPCB/SPCB norms.

• Efficient flare system designs will be ensured.

Solid Wastes

• Non-Hazardous Wastes includes organic wastes

• Proper documentation and manifestation of all wastes generated will be ensured.

• Pre-operation inspections will be conducted to ensure that waste disposal facilities are in place,




from kitchen, scrap metal, waste oil & surplus chemicals, sacks, broken wooden pallets.

• Hazardous waste

including drill cuttings from drilling activities.

• Litter and debris will not be discarded to sea and will be segregated before transferring to onshore base for final disposal.

• Biodegradable waste at the drilling site will be collected and transferred to onshore base for its treatment.

• Material such as scrap metal, waste oil & surplus chemicals will be disposed off in a controlled manner through authorized waste contractors.

• Drill cuttings generated during drilling operations will be separated from WBM followed by its discharge (as per G.S.R. 546 (E), dated 30/08/05).

• Provision for on-site waste segregation will be made by providing appropriate bins for different waste categories.

• Biodegradable waste can be used for composting. • Arrangements for proper disposal and waste

recycling contractors will be ensured. • It will be ensured that no drill cuttings (of any

composition) are discharged in sensitive areas as notified by MoEF.

Non-routine events and accidental releases (Well kicks, blow out)

• State of readiness will be maintained for quick response including plan awareness, training and regular exercises.

• Risk of loss of well control will be minimized by

▪ Proper well design, which will ensure that the hydrostatic weight of mud will overcome formation pressure.

▪ Proper drilling program design to ensure selection of properly rated blow out preventer equipment.

▪ Ensuring that the supervision team & Rig contractor’s relevant operating personnel are trained to handle well control situations and hold relevant well control training certificates.

▪ Ensuring advanced detection system is in place and BOP equipments are well maintained.

• Records of interaction between the management and the work force and records of training and drills will be maintained.

• It will be ensured that all available offset data is examined for proper design parameters.

• Same as above • Same as above • Provisions for well monitoring equipment to

detect influx from reservoir and Pressure detection service will be ensured.

• It will be ensured that Blowout preventers are regularly tested as per SOP.

• It will be ensured that spills are reported and cleared immediately.




• Spill Response (for all spills). Spill kits (comprising adsorbents; approved containers for storage and transport of spill wastes, disposable bags, gloves/goggles, etc.) will be made available on the drill site to handle spills.

Ecological Impacts • Waste management plan will be implemented to mitigate adverse impacts on the marine environment.

• Intimation to the Fisheries Department in case of any unusual phenomenon observed.

• Intimation to the Fisheries Department and/or Forest Department in case any deceased aquatic species is observed on the sea surface or any behavioural change observed in the avi-fauna.

• Formulation and implementation of waste management plan (as described in section 8.2) will be ensured.

• Visual observations of the aquatic flora & fauna will be done through the rig and surveillance vessels.

• Same as above.

Socio-Economic Impacts • Local people will be provided temporary employment during the project activities at supply base.

• Record of nature job/work will be maintained at supply base office.



8.3.1 WASTE MANAGEMENT PLAN The waste management plan is framed which will be subject to fine tuning depending on site conditions related to waste handling and disposal. This Waste management plan is as presented below in Table 8.3.

Table 8.3: Waste Management Plan

Waste Category Waste Type Proposed Action Domestic Waste Sewage • Sewage will be treated on-board of the rig

as per MARPOL regulations. Residual chlorine of the treated sewage will not exceed 1mg/L before disposal.

Kitchen Waste • Biodegradable waste from kitchen, laundries and galleys will be collected, segregated, stored in containers and will be transported onshore and used for composting.

Combustible Waste (Paper, Rags, Packing Material).

• Waste will be properly segregated (plastics, metal, glass) and transported to onshore base for sale to recycling contractor.

Recyclable Wastes Tin packs, plastic and glass bottles and other metallic materials

• Waste will be properly segregated and temporarily stored at onshore segregation pit. The waste will then be delivered to approved recycling contractor.

Non-Hazardous Wastes

Drill Cuttings • Cuttings free from WBM will be discharged offshore (as per G.S.R. 546 (E), dated 30/08/05) into sea intermittently, at an average rate of 50 bbl/hr/well from a platform so as to have proper dilution and dispersion without any adverse impact on marine environment.

• In case of drill cuttings associated with high oil content from hydrocarbon bearing formation, then it should be ensured that disposal of DC does not have oil content > 10 gm/kg.

Water Based Drilling Mud (WBM).

• As per G.S.R. 546 (E), dated 30/08/05, WBM/SOBM (is used in special case) will be recycled to the maximum extent. Unusable portion of WBM/SOBM (toxicity of 96 hr LC50 Value > 30,000 mg/L) will be discharged offshore into sea intermittently, at an average rate of 50 bbl/hr/well from a platform so as to have proper dilution and



Waste Category Waste Type Proposed Action

dispersion without any adverse impact on marine environment.

Drilling & Wash Wastewater

• Drilling and wash water will be treated to conform to limits notified under Environment Protection Act, 1986, before disposal into sea. The treated effluent will be monitored regularly.

Hazardous Waste Used Oil • Used oil will be collected in the designated containers. Vessels will be safely transported to onshore and sent to the approved recycling contractor for its disposal as per the norms notified by MoEF.

8.3.2 OIL SPILL CONTINGENCY PLAN

An effective response to oil spill is dependent on the extent of the preparedness of the organisation and the people involved. The objectives of the plan are:

• To develop appropriate and effective systems for the detection and reporting of spillage of oil.

• To ensure prompt response to prevent, control, and combat oil pollution.

• To ensure that adequate protection is provided to the public health and welfare, and the marine environment.

• To ensure that appropriate response techniques are employed to prevent, control, and combat oil pollution, and dispose off recovered material in an environmentally accepted manner.

• To ensure that complete and accurate records are maintained of all expenditure to facilitate cost of recovery.

An effective oil spill contingency plan should comprise four components:

a. Risk Assessment – To determine the risk of spills and expected consequences,

b. Strategic Policy – Defining roles and responsibilities, and providing summary of the rationale for operations,

c. Operational Procedures – Establishing procedures when spill occurs,

d. Information Directory – Collating support data.

While deciding the plan, it is equally important to take decisions on waste storage and options for treatment, disposal or reuse of waste, keeping in mind the environmental considerations and legal requisites. The Plan should include procedures for mobilizing the logistic support necessary for effective clean up, e.g. distribution of PPE and food for response team, adequate fuel for machinery and transport facility for labour, equipment and recovered wastes.



The Contingency Plan must also focus on timetable for exercises and training for all levels including marine and shoreline response teams and other interested parties. This will help in ensuring that contingency arrangements are in place and personnel have clear understanding of their responsibilities.

Information that should be included in immediate response strategy includes:

a. Actions required to be undertaken by the observer of an incident/the person that identifies that an incident has occurred.

b. Process for informing other site personnel (identifying various site roles).

c. Lines of communication and contact information (i.e. contact phone numbers, radio call protocol, etc.).

d. Steps to identify the most appropriate response strategy/strategies.

The Environmental Officer/Coordinator will be responsible for designing an appropriate post spill environmental monitoring program.

The Final Oil Spill Report should describe the following:

i. Name, location, organization, and telephone number,

ii. Name and address of the party responsible for the incident; or name of the carrier or vessel, or other identifying information,

iii. Date and time of the incident,

iv. Location of the incident,

v. Source and cause of the release or spill,

vi. Types of material(s) released or spilled,

vii. Quantity of materials released or spilled,

viii. Medium (e.g. land, water) affected by release or spill,

ix. Danger or threat posed by the release or spill,

x. Number and types of injuries or fatalities (if any),

xi. Weather conditions at the incident location,

xii. Whether an evacuation has occurred,

xiii. Other agencies notified or about to be notified,

xiv. Any other information that may help emergency personnel respond to the incident.



8.4 CAPITAL AND RECURRING COST FOR POLLUTION CONTROL MEASURES

The cost for the EMP implementation during drilling and installation and operation phase is given in Table 8.4.

Table 8.4: Environmental Budget

S. No.

Pollution Control Measures Capital Cost

(in INR Lakh) Recurring Cost (in INR Lakh)

1 Fuel, Lubricant and Chemical Management

35,000,000 5,00,000

2 Air emission mitigation Maintenance of D.G. sets.

3,00,000

3 Noise Mitigation Acoustic enclosure and Personal Protective Equipments. Maintenance cost of equipments.

50,00,000

3,00,000 4 Drilling Waste Management. 65,00,000 10,00,000 5 Environmental Monitoring Plan. 17,00,000

Total Cost 1,50,00,000 38,00,000

8.5 ENVIRONMENTAL AWARENESS TRAINING

Environmental Awareness training will help to ensure that the requirements of the EMP are clearly understood and followed by all project personnel throughout the project period. The primary responsibility for providing training as per HSE policy to all project personnel will be that of the HSE Officer. The HSE policy includes following guidelines:

• We are committed to maintain highest standards of occupational health, safety and environment protection.

• We will comply with all applicable codes and requirements to promote occupational health, safety and environment protection.

• We will be always alert, equipped and ready to respond to emergencies. • We will take all actions necessary to protect the integrity of the system in order to avoid

accidental release of hazardous substances. • We will enhance awareness and involvement in promotion of Occupational health, safety

and environment protection wherever we work and reside.

8.6 ENVIRONMENT MANAGEMENT CELL

An Environment Management Cell (EMC) will be formed, which will be responsible for implementation of the aforesaid project monitoring/management plans. The composition of the Environment Management Cell and responsibilities of its various members are given in Table 8.5.



Table 8.5: Environment Management Cell

S. No.

Designation Proposed Responsibility

1. Occupier (Environment)

Policy decisions and overall responsibility with respect to implementation of the EMP.

2. Deputy Management Representative (Environment)

• Responsible for management and implementation of EMP.

• Day to day monitoring of the implementation of EMP.

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SUMMARY AND CONCLUSION

9.1 INTRODUCTION

Adani Welspun Exploration Limited (AWEL) has been awarded the Offshore Contract Area MB/OSDSF/B9/DSF (B-9) Cluster and has signed the Revenue Sharing Contract (RSC) with the Government of India. AWEL intends to fast-track the project to produce the ‘first-gas’ from the field at the earliest.

The contract area MB/OSDSF/B9/2016 comprises of three (3) Discovered Small Fields (B-9, B-7 and BRC), located in the Mumbai Offshore Basin. While B-9 & B-7 are Gas Fields, BRC is an Oil Field. Well-Head platforms are aimed to be minimum facilities platforms which will be unmanned with periodical visits through helicopter to conduct routine maintenance, well maintenance and any other related repair work.

9.2 SUMMARY

The project involves offshore O&G development and production from DSF of B-9 cluster fields of 183.23 sq.km at Mumbai Offshore Basin. The EIA study for the proposed project includes establishment of the present environmental scenario in the proposed project area. EIA report consists of study of the specific activities related to the project and evaluation of the probable environmental impacts, thus leading to the recommendations of necessary mitigation measures. The entire EIA study has been carried out on the basis of the applicable environmental legislation, regulations and guidelines of the MoEF&CC.

In the drilling and installation phase of the project the barges & vessel movement, pipe-laying works and operating of generators will have maximum impact, especially on air, noise, vibration and ecological environment. Water quality and geology/soil will be affected due to the discharge of wastewater (construction and domestic) and leakage of oil etc; from generators and other equipments. On the other hand, during the operation phase; usage of maintenance & cleaning chemicals and risk of gas leakages will affect the water, air, noise and biological environment. With respect to occupational health, impacts are anticipated on the health of the employees during operation phase. Personnel working near the noise generating machines, DG sets and handling of chemicals and lubricants are more susceptible of getting health hazards.

However, all these impacts can be overcome with the mitigation measures proposed in Chapter 4 and EMP. Overall, this project will bring economic benefits, increase energy security of the country and generate employment opportunities.

9.3 CONCLUSION

From the Environmental Impact Assessment study, it can be concluded that this project under consideration will not have any major significant negative impacts with the mitigation measures are effectively and timely complied to. The measures must be followed by the strict implementation of Environmental Management Plan and Environmental Monitoring Plan.

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DISCLOSURE OF CONSULTANTS ENGAGED

10.1 INTRODUCTION

Asian Consulting Engineers Pvt. Ltd. (ACE) is an independent consulting company in the field of water and environment engineering with its headquarters located in New Delhi, India. ACE provides consulting services and sustainable solutions for infrastructure projects (roads, railways, ports, hydropower, water resources and other urban infrastructural plan outs), industrial projects (refineries, petrochemicals, gas pipelines, offshore and onshore oil & gas exploration, fertilizers, steel plants, power plants, textiles, hotels, distilleries and tanneries) and social development projects.

ACE is committed to provide consultancy services of international quality at local costs to suit its client’s requirements. ACE believes that the key to success is the ability to work effectively with clients to understand, define, and resolve their environmental concerns. ACE offers technical talent, specialized expertise, physical resources, and requisite facilities that are important in responding to water and environmental issues, the world faces today. The quality of work and timely completion of project are of paramount importance in each assignment that ACE undertakes.

We, at ACE, know what makes for a successful project. Clients turn to ACE because

• We understand the issue at hand. • Have the required experience and expertise to develop unique solutions. • Complete work on time and within budget. • Work towards client satisfaction as our ultimate goal.

ACE offers this combination of quality and performance through its professionals, managers and support personnel. Our people are equipped with state-of-the-art technologies and they are motivated to implement the project to the satisfaction of the client.

10.2 QUALITY OF SERVICES

ACE is committed to providing a high-quality consultancy service. As a recognition of same, ACE has been awarded ISO 9001:2015 certification by RINA, to provide consultancy services for Water Supply, Waste Water Treatment, Municipal Solid Waste Management, Environment and Social Impact Assessment, Environment Impact and Audit, Remote Sensing and Geographical Information Systems. In addition to this, ACE is also accredited with Quality Council of India (QCI) (Certificate No.: NABET/EIA/1417/SA030) for preparation of EIA of Onshore and Offshore Oil and Gas Exploration and Development and Transportation of Oil and Gas through Pipelines (Category A).

10.3 AREA OF SPECIALIZATION

• Environmental Management, • Water Resources Engineering, • Water Supply,

1100



• Wastewater Management, • Urban Environment Improvement, • Social Development, • GIS and Remote Sensing.

10.4 RESOURCES

Panel of Experts

ACE has experts in the following specialized areas:

• Water supply engineering, • Water resources engineering, • Wastewater engineering, • Solid waste management, • Public Health and Sanitation, • Environmental Management, • Forestry and Wildlife, • Environmental modeling, • Fisheries, • Aquaculture, • Social development.

Infrastructural Resources

Following facilities are available with ACE:

• Air quality models, • Noise quality models, • Water quality models, • Water distribution analysis software, • Sewer network analysis software.

Software Availability

• AERMOD, • CALINE 4, • ERDAS Imagine, • Arc GIS, • AutoCAD, • Map Info.

AANNNNEEXXUURREE -- II

12/19/2017 Report Part 1

http://environmentclearance.nic.in/auth/FORM_A_PDF.aspx?cat_id=IA/MH/IND2/71534/2017&pid=New 1/11

APPENDIX I(See Paragraph-6)

FORM 1

Note : If space provided against any parameter is inadequate,Kindly upload supporting document under'Additional Attachments if any' at the last part of the Form1. Please note that all such Annexures mustbe part of single pdf document.

(I) Basic InformationS.No. Item Details

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

No

1.

Name of the Project/s Development of B-9 Cluster Offshore fields in the DiscoveredSmall Field (DSF), Mumbai Offshore Basin.

Brief summary of project Annexure-Brief summary of projectProposal Number IA/MH/IND2/71534/2017Project Cost (in lacs) 160000

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

development & production Project Sector Industrial Projects - 2

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

Drilling and completion of 12 oil and gas wells, installation of 4well head platforms and laying of subsea pipelines (approx.130 km) ha.

4. New/Expansion/Modernization New

5. Existing Capacity/Area etc. 0 ha.

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

7. Does it attract the general condition? If yes,please specify No

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

9. Location of the project Mumbai Offshore BasinShape of the project land Block (Polygon)

Uploaded GPS file Annexure-GPS file Uploaded copy of survey of India Toposheet Annexure-Survey of india toposheetPlot/Survey/Khasra No. Not applicable as the project is located in offshore area.Town / Village Not applicable as the project is located in offshore area.State of the project Maharashtra

Details of State of the project

S.no State Name District Name Tehsil Name

(1.) Maharashtra Mumbai City Mumbai

10. Nearest railway station along with distance Delwada (Gujarat), 74 km

http://environmentclearance.nic.in/writereaddata/Online/TOR/11_Dec_2017_12353429779E1RQWEAnnexure-BriefSummaryoftheProject.pdf

http://environmentclearance.nic.in/auth/Testmap1.aspx?type=ca&fname=11_Dec_2017_123534290KZLWP9L4B9ClusterField.kml

http://environmentclearance.nic.in/download.aspx?files=writereaddata/Online/TOR/11_Dec_2017_123534290KZLWP9L4B9ClusterField.kml

http://environmentclearance.nic.in/writereaddata/Online/TOR/12_Dec_2017_112902390WHS7WISVAnnexure-SurveyofIndiaToposheet.pdf



in kmsNearest airport along with distance in kms Diu Airport (Daman and Diu), 72 km

11. Nearest Town/City/District Headquartersalong with distance in kms Diu (Daman and Diu) , 72 km

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

The proposed project is offshore development project. Theproject area is located beyond 12 nautical miles and falls inMumbai Offshore Basin.

13. Name of the Applicant Arvind

14. Registered Address Welspun House, 3rd Floor, Kamala City, Senapati Bapat Marg,Lower Parel (W), Mumbai 400013

15.

Address for correspondance:Name of the Company ADANI WELSPUN EXPLORATION LIMITEDName of the Applicant ArvindDesignation (Owner/ Partner/ CEO) VPPin code 400013E-mail [email protected] No. 022-66136296Fax No. 022-Copy of documents in support of thecompetence/authority of the person makingthis application to make application on behalfof the User Agency .

Annexure-Uploaded Copy of documents in support of thecompetence/authority

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

No

17. Whether part of Interlinked projects? No

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

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

20. If No, Reason N/A

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

No

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

No

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

No

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

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

24. Whether there is any litigation pending No

http://environmentclearance.nic.in/writereaddata/Online/TOR/11_Dec_2017_123534313DT5UMJKRAnnexure-Autherization.pdf



against the project and/or land in which theproject is proposed to be set up?(a) Name of the Court N/A(b) Name of the Sub court N/A(c) Case No. N/A(d) Orders/directions of the court, if any andrelevance with the proposed project N/A

(II) Activity

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

S.NoInformation/Checklist confirmation Yes/No

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

source of information data

1.1

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

No None as the project area is located in the offshore area.

1.2 Clearance of existing land, vegetation andbuildings? No None as the project area is located in the offshore area.

1.3 Creation of new land uses? No None as the project area is located in the offshore area.

1.4 Pre-construction investigations e.g. borehouses, soil testing? Yes

Geotechnical and Geophysical investigations involvingseabed sediment sampling and site survey will be carriedout prior to installation of the drilling rig unit, wellheadplatforms and subsea pipelines.

1.5 Construction works? Yes

Drilling and completion of 12 oil and gas wells (7 wells inB-9 field, 3 wells in B-7 &2 wells in BRC fields).Installation of 4 wellhead platforms (2 in B-9, and 1each in B-7 & BRC areas). Alternately sub-seacompletion wells may also be explored during the designstage. Laying of subsea pipelines approx. 130 km.Additionally, oil stabilisation, storage & loading facilitiesare also to be considered.

1.6 Demolition works? No Not applicable as the project is new. Hence, nodemolition will be done.

1.7 Temporary sites used for construction worksor housing of construction workers? No

The field is proposed to be operated unmanned withperiodical visits through helicopter/ boat-landing toconduct routine maintenance, well interventions and anyrepair work etc. During drilling and construction period,the crew and other operating staff will be accommodatedat offshore drilling unit, Derrick and / or Lay Barges(DLB) and Offshore supply vessels.

1.8Above ground buildings, structures orearthworks including linear structures,cutand fill or excavations and fill or excavations

No Not applicable as the project area is located in theoffshore area.

1.9 Underground works including mining ortunneling?

No There are no mining or tunneling works however drillingof offshore wells involves drilling through subsurfacelayers beneath the seabed till the target depth isreached. The wells will be deviated wells and horizontal



displacement of around 1500m, True Vertical Depth(TVD) of 2500 m to 4000 m.

1.10 Reclamation works? No

1.11 Dredging? No

1.12 Offshore structures? Yes

Offshore drilling unit will be anchored temporarily atdrilling location for drilling of wells. On completion ofdrilling, drilling rig will be released and towed away tonext location. Drilling and completion of 12 oil and gaswells (7 wells in B-9 field, 3 wells in B-7 &2 well in BRCfields). Installation of 4 wellhead platforms (2 in B-9,and 1 each in B-7 & BRC areas. Alternately sub-seacompletion wells may also be explored during designstage. Subsea pipelines approx. 130 km.

1.13 Production and manufacturing processes? Yes

Processing of the oil and gas is envisaged to be doneatexisting third party facilities, gas will be further routedto an existing on-shore gas processing complex fromwhere the gas buyers’ off take point will be identifiedlater. The BRC Oil production is envisaged to bestabilized in the BRC platform and exported at offshore,the details will be finalized later.

1.14 Facilities for storage of goods or materials? Yes

Oil stabilisation, storage & loading facilities are also tobe considered under the proposed project. The detailsare to be finalised during the design phase of thedevelopment.

1.15 Facilities for treatment or disposal of solidwaste or liquid effluents? Yes

Offshore drilling unit will have an onboard drill cuttingsseparation and washing facility. Waste water (sewage &wash water) treatment facility will be available at drillingrig and barges/vessel. The drill cuttings and WBM will bedischarged as per MoEF notification G.S.R. 546(E). Incase SOBM is used, it will communicate to MoEF&CC orSPCB. Unused mud will be brought back to the land fortreatment & disposal as per MoEF notification G.S.R. 546(E).

1.16 Facilities for long term housing ofoperational workers? No

1.17 New road, rail or sea traffic duringconstruction or operation? Yes Offshore vessels movement.

1.18

New road, rail, air water borne or othertransport infrastructure including new oraltered routes and stations, ports, airportsetc?

No

1.19Closure or diversion of existing transportroutes or infrastructure leading to changesin traffic movements?

No

1.20 New or diverted transmission lines orpipelines? Yes

Laying of approx. 130 km subsea pipelines i.e. Approx.80 km sub-sea pipeline (upto 10”) from B-9 field tonearby operator’s existing well head platform. Approx.10 km intra-field sub-sea pipeline (upto 8”) within B-9area. Approx. 30 km sub-sea pipeline (upto 8”) from B-7platform/ area to B-9 platforms /area. Approx. 10 kmsub-sea pipeline (upto 6”) from BRC platform/ area toB-7 platform /area or B-9 platforms/ area. They will behooked up with platform facilities.

1.21 Impoundment, damming, culverting,realignment or other changes to the

No



hydrology of watercourses or aquifers?

1.22 Stream crossings? No

1.23 Abstraction or transfers of water fromground or surface waters? Yes

Sea water will be used after basic treatment for washingand other non-domestic purposes, during drilling andoffshore installation period. Fresh water will be sourcedfrom nearby sea port for domestic and drilling purposes.

1.24 Changes in water bodies or the land surfaceaffecting drainage or run-off? No

1.25 Transport of personnel or materials forconstruction, operation or decommissioning? Yes

Transport of materials will be done using supply vesselsfrom nearby port facility to project location. Transfer ofpersonnel will be through helicopters and/or vessels.

1.26 Long-term dismantling or decommissioningor restoration works? Yes

At the end of the field life (presently envisaged to be 10years) the permanent structures at offshore includingplatform will be decommissioned. The subsea pipelineswill be removed of hydrocarbons.

1.27Ongoing activity during decommissioningwhich could have an impact on theenvironment?

No

1.28 Influx of people to an area in eithertemporarily or permanently? Yes

The field is proposed to be operated unmanned withperiodical visits through helicopter/ boat-landing toconduct routine maintenance, well interventions and anyrepair work etc. During drilling and well platforms & sub-sea pipelines installation period, technical and non-technical personnel will be temporarily placed at drillingrig, DLB & Offshore Vessels

1.29 Introduction of alien species? No

1.30 Loss of native species or genetic diversity? No

1.31 Any other actions? No

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


Details thereof (with approximatequantities/rates, wherever possible) with


2.1 Land especially undeveloped or agriculturalland (ha) No None as the project area is located in the offshore area.

2.2 Water (expected source & competing users)unit: KLD Yes Approximately 45-55KL/day for each well. Sea water

and fresh water will be used.

2.3 Minerals (MT) Yes Around 80-100 MT of Bentonite and 200-300 MT ofBarytes for each well.

2.4 Construction material – stone, aggregates,sand / soil (expected source – MT) No

2.5 Forests and timber (source – MT) No

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

Yes 8-12 KL per day of High Speed Diesel (HSD) for runningcaptive Gensets of Drilling rigs, DLB, Offshore Vesselsduring drilling and construction phase. Power generation



through solar or other sources will be used at unmannedwellhead platforms.

2.7 Any other natural resources (use appropriatestandard units) No

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




3.1

Use of substances or materials, which arehazardous (as per MSIHC rules) to humanhealth or the environment (flora, fauna, andwater supplies

No

3.2Changes in occurrence of disease or affectdisease vectors (e.g. insect or water bornediseases)

No

3.3 Affect the welfare of people e.g. by changingliving conditions? No

3.4Vulnerable groups of people who could beaffected by the project e.g. hospital patients,children, the elderly etc.

No

3.5 Any other causes No

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




4.1 Spoil, overburden or mine wastes Yes Drilled cuttings generated will be about 300 - 500 M3during drilling over a period of 45-60 days

4.2 Municipal waste (domestic and orcommercial wastes) Yes

Food, sanitary and other municipal wastes generatedfrom the accommodation facility on the offshore drillingunit, DLB & Offshore Vessels will be segregated atsource (organic and inorganic) and disposed accordingly.

4.3 Hazardous wastes (as per Hazardous WasteManagement Rules) Yes

Waste drilling mud and drill cuttings containing oil aboveprescribed limits have been categorized as hazardouswaste. Water Based Mud (WBM) is planned to be used.In case, Synthetic Oil Base Mud (SOBM) is used, it willbe communicated to MoEF&CC/SPCB. Unused mud willbe brought back to land for treatment & disposal as perMoEF notification G.S.R. 546 (E). Oil filters, Burnt/Spentoil & used batteries/lead acid cells will be brought backfurther disposal through authorized recycling vendor.

4.4 Other industrial process wastes YesFormation/Produced water, if any, separated during gasprocessing will be processed at existing processingfacilities for treatment and disposal.



4.5 Surplus product No

4.6 Sewage sludge or other sludge from effluenttreatment Yes

Sewage treatment plants (STPs) are available on boardrig & DLB as per MARPOL & marine practices anddischarged into the sea after treatment during thedrilling and construction phase.

4.7 Construction or demolition wastes No

4.8 Redundant machinery or equipment No

4.9 Contaminated soils or other materials No

4.10 Agricultural wastes No

4.11 Other solid wastes No

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




5.1 Emissions from combustion of fossil fuelsfrom stationary or mobile sources Yes

The sources of emissions anticipated are DieselGenerator (DG) sets on the offshore drilling units, DLB,and exhausts from supply vessels. Low sulphur HSDcommercially available as fuel (approx8-12 KLD) for DGsets. Considering the drilling location is entirely off-shore, there will good dispersion and no perceptibleimpact on the air quality.

5.2 Emissions from production processes Yes Test flaring of gas per well is expected to be of about 4days per well.

5.3 Emissions from materials handling includingstorage or transport Yes Exhaust emissions from supply vessels is anticipated.

5.4 Emissions from construction activitiesincluding plant and equipment No

The source of air emissions anticipated from offshoredrilling are those resulting from combustion of fuel in

Diesel Generator sets on the offshore rigs, and exhaustemissions from supply vessels.

5.5Dust or odours from handling of materialsincluding construction materials, sewage andwaste

No

5.6 Emissions from incineration of waste No

5.7 Emissions from burning of waste in open air(e.g. slash materials, construction debris) No

5.8 Emissions from any other sources No

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






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

Yes Noise will be generated from the Drilling Rig & DLBgenerators however since the operation is offshore,away from habitation adverse impacts are notanticipated.

6.2 From industrial or similar processes No

6.3 From construction or demolition No

6.4 From blasting or piling No

6.5 From construction or operational traffic Yes The major sources of noise generation are from SupplyVessel and Helicopter Movements.

6.6 From lighting or cooling systems No

6.7 From any other sources No

7 Risks of contamination of land or water from releases of pollutants into the ground or into sewers,surface waters, groundwater, coastal waters or the sea:




7.1 From handling, storage, use or spillage ofhazardous materials Yes

HSD for DG sets at Drilling rigs, DLB & Offshore Vesselsand chemicals required for drilling mud preparation willbe stored. There can be potential spillages duringtransfer of HSD from supply vessel to offshore drillingunits also called as bunkering. Emergency in the form ofwell blow-out could occur if the well gets out of controland all barriers are lost. Spill contingency plan and otherindustrial best practises will be made available to avoidsuch risks.

7.2From discharge of sewage or other effluentsto water or the land (expected mode andplace of discharge)

No

Treated Sewage and bilge / deck wash wastewaterdisposed as per MARPOL guidelines. Miscellaneouswastes like paper, packing material, plastic, scrapmaterial, non reusable metal cans, filters, are collectedin separate containers and dispatched to land base fordisposal.

7.3 By deposition of pollutants emitted to air intothe land or into water No

7.4 From any other sources No

7.5Is there a risk of long term build up ofpollutants in the environment from thesesources?

No

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




8.1 From explosions, spillages, fires etc fromstorage, handling, use or production of

Yes Drilling operations are exposed to risks of fire, oil spillsmainly from possible spillage of bunker oil, well



hazardous substances complication resulting in well blow outs. Though theseare rare events, preventive safety features are includedin the design. Fire, blowout and oil spill contingencyplans are developed before commencement ofoperations for all the identified risks. Regular safetyaudits, maintenance schedules are adhered during theoperations to reduce equipment failures and preventionof accidents.

8.2 From any other causes YesOthers potential risks that will be assessed as part of therisk assessment studies are those from fire in dieselstorage, collisions and structural failures.

8.3

Could the project be affected by naturaldisasters causing environmental damage(e.g. floods, earthquakes, landslides,cloudburst etc)?

Yes

Drilling operation & installation of offshore facilities couldget affected during cyclones or storm conditions withhigh intensity wind and wave action. Drilling rigschartered for drilling operations & other vessels/bargesfor installation of offshore facilities, have adequatesafety and early warning systems and have setprocedures for suspending operations during unsafeweather conditions & securing safe anchor. However,project activities will be carried out during fair weatherconditions.

9Factors which should be considered (such as consequential development) which could lead toenvironmental effects or the potential for cumulative impacts with other existing or plannedactivities in the locality

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

quantities/rates, wherever possible) withsource of information data

9.1

Lead to development of supporting utilities,ancillary development or developmentstimulated by the project which could haveimpact on the environment e.g.:

Supporting infrastructure (roads, powersupply,waste or waste water treatment,etc.)housing developmentextractive industriessupply industriesOther

No

9.2 Lead to after-use of the site, which couldhave an impact on the environment No

9.3 Set a precedent for later developments No

9.4Have cumulative effects due to proximity toother existing or planned projectswith similar effects

No

(III) Environmental Sensitivity

S.No Areas Name/Identity Aerial distance (within 15km.) Proposedproject location boundary



1 Areas protected under internationalconventions, national or local legislation for their ecological, landscape, cultural or otherrelated value

No

2

Areas which are important or sensitive forecological reasons - Wetlands, watercoursesor other water bodies, coastal zone,biospheres, mountains, forests

No

3

Areas used by protected, important orsensitive species of flora or fauna forbreeding, nesting, foraging, resting, overwintering, migration

No

4 Inland, coastal, marine or undergroundwaters Yes Marine Waters.

5 State, National boundaries No Proposed Project is located beyond 12 nauticalmiles from shoreline.

6Routes or facilities used by the public foraccess to recreation or other tourist, pilgrimareas

No

7 Defence installations No

8 Densely populated or built-up area No

9Areas occupied by sensitive man-made landuses (hospitals, schools, places of worship,community facilities)

No

10Areas containing important, high quality or scarceresources.(ground water resources,surfaceresources,forestry,agriculture,fisheries,tourism,minerals)

No

11Areas already subjected to pollution orenvironmental damage.(those where existinglegal environmental standards are exceeded)

No

12

Areas susceptible to natural hazard whichcould cause the project to presentenvironmental problems (earthquakes,subsidence, landslides, erosion, flooding orextreme or adverse climatic conditions)similar effects

No

(IV) Proposed Terms of Reference for EIA studies

1 Uploaded Proposed TOR File Annexure-TOR file

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

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

4 Uploaded additional attachments(onlysingle pdf file) NIL

(V) UndertakingI hereby give undertaking that the data and information given in the application and enclosures aretrue to be best of my knowledge and belief and I am aware that if any part of the data and

http://environmentclearance.nic.in/writereaddata/Online/TOR/11_Dec_2017_155150117NUSMESH5Annexure-ProposedTORfile.pdf

http://environmentclearance.nic.in/writereaddata/Online/TOR/11_Dec_2017_155150147G2BAKC96CoveringLetter.pdf

http://environmentclearance.nic.in/writereaddata/Online/TOR/11_Dec_2017_1551501533HEF0QIUAnnexure-Pre-feasibilityReport(PFR)File.pdf



information found to be false or misleading at any stage, the project will be rejected and clearancegiven, if any to the project will be revoked at our risk and cost.

V.(i)

Name of Applicant ArvindDesignation VPName of Company (Applicant Nameshould not be given here) ADANI WELSPUN EXPLORATION LIMITED

Address Welspun House, 3rd Floor, Kamala City, Senapati Bapat Marg,Lower Parel (W), Mumbai 400013

Print

MB-OSDSF-B9/2016 B9 CLUSTER DEVELOPMENT

Document No.: AWEL-RX-B9 Cluster-PFR-0001

Project Feasibility Report

1 27.11.17 Issued for EIA study LS AS/VIM AH

0 25.10.17 Issued for Review LS AS/VIM AH

Rev Date Purpose of Issue Prepared By Reviewed By Approved By

Project Feasibility Report- DSF B9 development Project

i

Table of Content

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

2. Project details ............................................................................................................................... 1

3. Fields development concept ........................................................................................................ 2

4. Scope of Project ........................................................................................................................... 4

5. Drilling & completion philosophy .................................................................................................. 4

6. Surface facilities ........................................................................................................................... 5

7. Resources: ................................................................................................................................... 5

8. Rejects: ........................................................................................................................................ 6

9. Development schedule ................................................................................................................. 6

10. Development costs ....................................................................................................................... 7

11. HSES requirements ...................................................................................................................... 7

12. De-commissioning ........................................................................................................................ 7

13. List of abbreviations ..................................................................................................................... 8

Annexure A: Production profile ............................................................................................................. 9


1

1. Executive Summary

Adani Welspun Exploration Limited (AWEL) “Company” has been awarded contract area MB/OSDSF/B9/2016 comprising of B9 Cluster and has signed the Revenue Sharing Contract (RSC) with the Government of India. The field was originally discovered by ONGC and was subsequently offered for bidding under Discovered Small fields (DSF) bid round. Adani Welspun Exploration Limited (AWEL) is a joint venture E&P Company formed by two Indian based multinational business conglomerates Adani Group and Welspun Group to undertake upstream oil & gas business with 65% and 35% shares respectively. AWEL plans to develop the B9 Cluster field by drilling wells and installing offshore facilities to produce natural gas and crude oil. The Project Feasibility Report (PFR) provides an outline of the overall plan to for the development of B9 Cluster fields 2. Project details

Justifications for the project: Government of India through Directorate General of Hydrocarbons (DGH) invited bids from companies to develop the DSF fields with the objective of reducing the huge import of hydrocarbons and encourages the speedy implementation of the development. The local hydrocarbon production is about 20% of the demand. B9 Offshore Cluster details The contract area MB/OSDSF/B9/2016 comprises of three DSF fields offshore namely B-9, B-7 and BRC located in the Mumbai Offshore Basin (Figure 1). While B-9 & B-7 are gas fields, BRC is an Oil field.

Figure 1: Location Map of Contract Area MB/OSDSF/B9/2016)


2

The latitude & longitude of the B-9 Cluster is shown in the table below.

Table 1: Longitude and Latitude measurements for the Contract Area MB/OSDSF/B9/2016 The P50 hydrocarbon in-place volumes of B-9, B-7 and BRC are 158.4 Bcf, 69.5 Bcf and 73 MSTB respectively, as estimated by ONGC and provided in the pre-bid technical information through DGH. 3. Fields development concept

Being a discovered small field no additional exploration activities are planned. Offshore geo-technical & geo-physical surveys will be undertaken to design and execute the development activities including drilling and installation of platforms and sub-sea pipelines. The following are the details in which the three fields are planned to be developed. B-9 field: 7 wells are proposed to be drilled. Peak production rate is expected to be about 32 mmscfd for a plateau period of 4 years followed by declining profiles (refer Annexure A), the estimated field life is currently estimated to be 10 years. B-7 Field 3 wells are proposed to be drilled. Peak production rate is expected to be about 21


3

mmscfd (Annexure A) the field life is estimated to be 10 years. BRC field : Current plan is to drill two wells in the BRC field, the peak production rate is expected to be about 800 bopd & 0.4 mmscfd for a plateau period of 2 years followed by declining profiles. The studies for estimating the field production profiles are currently ongoing. Process technology Minimum facilities platforms are considered for oil and gas production and no processing facilities are envisaged. Platform jackets being considered as mono- towers or three-legged Jackets or alternatives. Sub-sea completions of wells may also be explored as options if economically viable.

Talks are in advanced stages with a nearby operator for sharing their gas export and processing facilities. The combined wellhead fluids will be routed to the nearby Operator’s existing well head platform through a dedicated pipeline. Processing of the oil and gas is envisaged to be done by nearby operator’s existing facilities, gas will be further routed to an existing on-shore gas processing complex from where the gas buyers’ offtake point will be identified later. No onshore facilities are envisaged in the current concept. The BRC Oil production is envisaged to be stabilised in the BRC platform and exported at offshore, the details will be finalised later. The field is proposed to be operated unmanned with periodical visits through helicopter/ boat-landing to conduct routine maintenance, well interventions and any repair work etc.


4

Figure 2: Conceptual plan for B9 DSF Cluster fields development

4. Scope of Project

The overall scope of the current development project comprises of Drilling of 12 wells, 7 wells in B-9 field, 3 wells in B-7 & 2 well in BRC fields, Installation of two wellhead platforms in B-9 area, and one each in B-7 & BRC

areas. Alternately sub-sea completion wells may also be explored during the design stage.

Laying of approx. 80 km sub-sea pipeline (upto 10”) from B9 field to a nearby operator’s existing well head platform and hooking-up with the platform facilities.

Laying of approx. 10 km intra-field sub-sea pipeline (upto 8”) within the B-9 area and hooking-up with the platform facilities.

Laying of approx. 30 km sub-sea pipeline (upto 8”) from B-7 platform/ area to B-9 platforms /area and hooking-up with the platform facilities.

Laying of approx. 10 km sub-sea pipeline (upto 6”) from BRC platform/ area to B-7 platform /area or B-9 platforms/ area and hooking-up with the platform facilities. Additionally, oil stabilisation, storage & loading facilities are also to be considered. The details are to be finalised during the design phase of the development.

5. Drilling & completion philosophy

The development drilling & completion work are planned to be performed using a Jack-up rig at the wellhead platform. The wells will be deviated wells and horizontal displacement of around 1500m, TVD of 2500 m to 4000 m. Wells are tentatively planned to be drilled with 4 casing policy having 30” Conductor, 20” surface casing, 13-3/8” & 9 5/8” Intermediate casings and 7’ Production Liners. Completion strings will be 3 ½” Tubings with gas-tight connections. Wells are planned to be completed with sand-screens. The wellheads planned are integrated wellhead-4CP 10K type with matching Christmas-trees. The drilling fluids are planned to be of high performance water-based muds, or SOBM. Test flaring per well is expected to be of about 4 days per well. The drilling rigs and the spread including supply vessels, etc. will be primarily run on diesel and power will be generated within the rigs/ vessels through diesel generators. Maximum capacity of cranes is expected to be 100 T.

The Drilling Contractor is expected to handle the logistics of transporting material and consumables & chemicals viz. Bentonite, Barite, Cement etc. to & fro offshore through warehouse facilities located inland.


5

6. Surface facilities

The production of oil and gas in the field will be from up to 12 wells. Gas produced from the wells will be co-mingled and sent to a nearby operator’s existing wellhead platform in located about 80 km away. The two platforms within B-9 field are located at a distance of 10 km between. The platforms are envisaged to be minimum facilities wellhead platforms comprising of wellhead, Christmas tree, production & test manifold, wellhead control panel, scrapper launcher., instrument gas system, local power generation (solar or other), heli-deck, jib-crane, fiscal metering, real time production data transfer to DGH through satellite communication, etc.

The inter-platform sub-sea pipeline of size 6” for a length of about 10 km will be laid at the same time with the installation of main pipeline. This spur line is planned to be either routed to the wellhead platform or tied-in to the 8”-10” sub-sea main pipeline. On-bottom stability analysis study will be performed at the design stage and appropriate requirements for protection of pipeline, environment & other consideration like security, etc. will be finalised at the time. The development for B-7 field & BRC field will include installation of 2 wellhead platforms, inter-field sub-sea pipelines and hooking up at B-9 area The BRC platform is also envisaged to include facilities to handle, stabilise, store and export oil. The project is planned to be executed through a reputed EPIC Contract and the Contractor would perform detailed design, procure, fabricate/ construct platforms & jackets, install platforms, jackets & pipeline, hook-up and commission. The platforms & Jackets will be fabricated at a remote fabrication yards (in India or abroad), transported to the offshore field through barges, installed and commissioned. The pipelines will be sourced from reputed mills, corrosion/weight coated, transported to the field through barges/ vessels, installed sub-sea, hooked up with the platforms and commissioned. The installation spread including derrick and lay barges, supply vessels, etc. will be primarily run on diesel and power generated within the rigs/ vessels through diesel generators. Maximum capacity of Cranes is expected to be 1000 T. 7. Resources:

This is an offshore development project beyond 12 nautical miles, and is planned to be executed through lump-sum integrated project management (IPM) and Engineering, Procurement, Construction, Installation & commissioning (EPIC) models. Construction materials like sand, brick, stone chips, borrow pits, etc. is not envisaged for this project.


6

8. Rejects: No pollution potential rejects are envisaged in this project

9. Development schedule The high level development schedule of all the three fields in Contract area MB-OSDSF-B9-2016 is as given below:

B-9 DSF - Tentative Development Schedule2017

Key Events Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4

B-9 Field

FDP and Project Planning

Project Execution through IPM and EPIC

First Gas

B-7-Field



First Gas

BRC Field



First Oil

2018 2019 2020 2021 2022


7

10. Development costs

The overall development is expected cost tentative is about US$ 250 million (Indian Rupees 1600 Crores). 11. HSES requirements

The Facilities shall be designed and constructed as per standard existing oilfield practices, and are to be operated and maintained to meet the safety philosophies and criteria outlined hereunder. Key elements in achieving the safety objectives are: The facilities shall be designed, constructed, and are to be operated and maintained

such that they are fail-safe and of high safety integrity. The selected process configuration and equipment shall have proven safety and

operability characteristics. The Facilities engineering design processes shall include thorough quantitative and

qualitative safety case assessments and safety reviews, including the HAZOP process etc.

The Facilities shall be constructed, installed and are to be operated and maintained in accordance with safe work practices and procedures. The target site safety objective shall be zero lost time injury (LTI) frequency rate.

Site emergency response and evacuation procedures shall be developed and personnel will be trained /instructed in these procedural requirements.

All statutory compliance such as Environmental Clearance (EC), approvals from OISD, State Maritime board, Defence / MHA/ MoD Clearances etc. shall be strictly enforced.

Safety studies such as HAZID, HAZOP, SIL Safety case, material handling, etc. would to be conducted and all action items closed. All documentation shall be properly maintained and made available to Authorities for verification.

The wells shall be drilled as per API & OISD standards. Drilling equipment and services shall be selected as per the above Guidelines.

All well related safety devices such as Blow-out Preventers (BOP), Safety valves, etc. shall be tested as per API, OISD or other Statutory Guidelines and records kept.

Proper training shall be ensured for all crew personnel and adequate safety-kits shall be used all time.

12. De-commissioning

At the end of the life of the field, the offshore platform facilities will be decommissioned as per the national/ international standards required for Abandonment/ Site restoration. The wells will be plugged, safely abandoned and the structures and equipment will be dismantled and disposed as per the norms.


8

13. List of abbreviations

API American Petroleum Institute OISD Oil Industry Safety Directorate

bbl barrel MoEF&CC Ministry of Environment & Forest and Climate Change

bpd Barrels per day LTI Lost Time Incident CGR Condensate Gas ratio DSF Discovered Small Field SIL Safety Integrity Levels EC Environmental Clearance TVD True Vertical Depth EPIC Engineering Procurement

Installation & Commissioning

EUR Expected Ultimate Recovery FDP Field Development Plan FEED Front-end Engineering Design HAZOP Hazardous Operability studies HAZID Hazard Identification studies MHA Ministry of Home Affairs MD Maximum Depth MoD Ministry of Defence MPFM Multi-phase Flow meter IPM Integrated Project

Management


9

Annexure A: Production profile

A.1 Overall indicative Production profile for B-9 field B-9 Profile B-7 Profile

Date Gas Cum Gas Number Gas Cum Gas Number

(dd-mm-yyyy)

Rate Produced of Rate Produced of

(MMscf/day) Bscf Producers (MMscf/day) Bscf Producers

4/1/2019 15.0 0.0 3.0

4/1/2020 32.0 11.7 7.0

4/1/2021 32.0 23.4 7.0 21.0 7.7 3.0

4/1/2022 32.0 35.1 7.0 21.0 15.3 3.0

4/1/2023 25.4 46.1 7.0 21.0 23.0 3.0

4/1/2024 16.6 53.7 7.0 21.0 30.7 3.0

4/1/2025 10.5 58.6 7.0 13.6 35.6 3.0

4/1/2026 6.5 61.7 7.0 8.8 38.9 3.0

4/1/2027 3.9 63.6 7.0 5.7 41.0 3.0

4/1/2028 1.8 64.4 7.0 3.7 42.3 3.0

4/1/2029 1.2 64.9 7.0 2.4 43.2 3.0

4/1/2030 1.6 43.8 3.0

Production potential from BRC field is being evaluated. Profiles will be estimated after detailed G&G evaluation.

AANNNNEEXXUURREE -- IIII

ANNEXURE – III Vessel Pictures and

Documents (Hired for Baseline Monitoring)



Sampling Vessel for baseline monitoring (Phalguni Boat).

Sampling Vessel for baseline monitoring.



Insurance Papers of Boat ( Phalguni Boat).



Phalguni boat Registration Document.

ANNEXURE – IV ODAG Clearance

Document



ODAG Clearance Documents.

ANNEXURE – V

Demobilization Letter to FODAG from Adani

ANNEXURE - VI ODAG Inspection

Pictures



ODAG Inspection Pictures.

ANNEXURE – VII Data Log Images



GPS Log Data Pictures

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