Environmental Impact Assessment for drilling of an...

Environmental Impact Assessment for drilling of an

exploratory well in the NELP-VII block MB-OSN-2005/3

of

Western Offshore Basin

Corporate Health, Safety and Environment Management

New Delhi

November 2015

Acknowledgement

Environmental Impact Assessment and Risk assessment report for proposed exploratory drilling activity

in MB-OSN-2005/3 in Western Offshore Basin has been prepared by the HSE Team of Western Offshore

Basin, Mumbai under the guidance and support from the Corporate HSE, ONGC, New Delhi. The primary

baseline data with the analytical observations has been provided by IPSHEM, Goa. The report

incorporates the offshore environmental baseline data acquired under the project Western Offshore

Environment Monitoring conducted and carried out by IPSHEM, Goa.

We express our sincere gratitude to Shri A.K. Dwivedi, Director (Exploration), I/c HSE, ONGC for his

encouragement and support in preparation of this report. Our sincere thanks are due to Shri G.C. Katiyar,

ED-Basin Manager, Western Offshore Basin and Shri S. Ganesan, GGM-HOI, IPSHEM for providing

guidance during the course of this work.

Project Team

Contents

SL.NO. PAGE NO.

CHAPTER 1 INTRODUCTION 1

1.1 PURPOSE 1

1.2 IDENTIFICATION OF THE PROJECT PROPONENT & THE

PROJECT 2

1.3 SCOPE OF STUDY 4

CHAPTER 2 TERMS OF REFERENCE 5

2.1 POINTWISE COMPLIANCE OF TOR 5

CHAPTER 3 PROJECT DESCRIPTION

3.1 TYPE OF THE PROJECT 10

3.2 LOCATION OF PROJECT 11

3.2.1 CRZ REGULATION APPLICABILITY 13

3.2.2 DRILLING WELL LOCATION 13

3.3 PROPOSED PROJECT SCHEDULE FOR APPROVAL AND

IMPLEMENTATION 14

3.4 TECHNOLOGY AND PROCESS DESCRIPTION 14

3.4.1 SOURCE OF WATER 19

3.4.2 WATER USAGE PLAN 19

3.4.3 WASTEWATER GENERATION & DISCHARGE 20

3.4.4 CHEMICAL REQUIREMENTS AND THEIR STORAGE AT RIG 21

3.5 LITIGATIONS & COURT DIRECTIONS / ORDERS 22

3.6 ASSESSMENT OF NEW AND UNTESTED TECHNOLOGY 22

3.7 CLIMATOLOGY & METEOROLOGY OF THE ARABIAN SEA 23

CHAPTER 4 DESCRIPTION OF ENVIRONMENT 30

4.1 STUDY AREA 30

4.2 STUDY COMPONENTS 30

4.3 BASELINE ENVIRONMENT 31

4.3.1 OBJECTIVES AND SCOPE OF THE STUDY 31

4.3.2 SCOPE OF WORK 31

4.3.3 METHODOLOGY 32

4.3.4 ASSOCIATION OF BIOLOGICAL EXPERTISE 33

4.3.5 DESCRIPTION OF STUDY AREA AND SAMPLING

LOCATIONS 34

4.3.6 EQUIPMENT USED FOR SAMPLING: 36

4.3.7 METHODOLOGY FOLLOWED FOR HYDROGRAPHICAL AND

CHEMICAL PARAMETERS 38

4.3.7.1 HYDROGRAPHICAL PARAMETERS 38

4.3.7.2 CHEMICAL PARAMETERS 39

4.3.8 RESULTS AND DISCUSSION 41

4.3.8.1 TEMPERATURE 41

SL.NO. PAGE NO.

4.3.8.2 PH 41

4.3.8.3 SALINITY 41

4.3.8.4 TURBIDITY 41

4.3.8.5 TOTAL SUSPENDED SOLIDS 42

4.3.8.6 DISSOLVED OXYGEN DO 42

4.3.9 BIOLOGICAL MONITORING OF OFFSHORE STATIONS 46

4.3.9.1 METHODOLOGY OF BIOLOGICAL ANALYSIS 46

4.3.9.1.1 COLLECTION AND ANALYSIS OF CHLOROPHYLL-A 46

4.3.9.1.2 COLLECTION AND ANALYSIS OF PHYTOPLANKTON: 46

4.3.9.1.3 ZOOPLANKTON COLLECTION AND ANALYSIS 47

4.3.9.1.4 FISH & FISHERY 48

4.3.9.2 RESULTS AND DISCUSSION 49

CHAPTER 5 ANTICIPATED ENVIRONMENTAL IMPACTS AND

MITIGATION MEASURES 79

5.1 ENVIRONMENTAL IMPACTS IDENTIFIED 79

5.1.1 IMPACTS ON MARINE WATER AND SEDIMENT: 80

5.1.2 GENERATION & IMPACTS OF NOISE 82

5.1.3 MARINE ECOLOGICAL IMPACTS 84

CHAPTER 6 ENVIRONMENTA MANAGEMENT PLAN 85

6.1 MUD MAKE-UP AND MUD & CUTTINGS DISPOSAL 85

6.2 MEMBERSHIP OF COMMON DISPOSAL FACILITIES 85

6.3 MEASURES TO HANDLE OILY WASTE DISCHARGES 85

6.4 SEWAGE TREATMENT AND DISPOSAL 89

6.5 SOLID WASTE HANDLING 89

6.6 SPENT OIL HANDLING 87

6.7 OIL HANDLING FROM WELL TEST OPERATIONS 87

6.8 NOISE ABATEMENT MEASURES 87

6.9 MEASURES TO MINIMIZE DISTURBANCE DUE TO LIGHT

AND VISUAL INTRUSIONS 88

CHAPTER 7 ANALYSIS OF ALTERNATIVES (TECHNOLOGY AND SITE)

7.1 DRILLING LOCATIONS 89

CHAPTER 8 ENVIRONMENTAL MONITORING PROGRAMM 91

8.1 BUDGET AND PROC. SCHEDULES OF ENVIRONMENTAL

MONITORING 91

CHAPTER 9 ADDITIONAL STUDIES

9.1 RISK ASSESSMENT 92

9.1.1 STAGES FOR WHICH RISK ASSESSMENTS ARE

UNDERTAKEN 92

9.1.1.1 OBJECTIVE OF QRA 93

9.1.1.2 RISK ASSESSMENT METHODOLOGY 94

9.1.1.3 HAZARD IDENTIFICATION 95

SL.NO. PAGE NO.

9.1.1.4 FREQUENCY ANALYSIS 95

9.1.1.5 CONSEQUENCE ANALYSIS 96

9.1.1.6 RISK EVALUATION 97

9.1.2 KEY RISKS INVOLVED 98

9.1.2.1 BLOWOUTS 99

9.1.2.2 COLLISIONS INVOLVING MODU (JACK-UP DRILLING RIG) 101

9.1.2.3 HELICOPTER CRASHES 102

9.1.3 RISK MITIGATION MEASURES 104

9.1.3.1 WELL PLANNING & DESIGN 104

9.1.3.2 SELECTION OF EQUIPMENT, SYSTEMS AND PEOPLE 108

9.1.3.3 TESTING AND MAINTENANCE OF CRITICAL EQUIPMENT 109

9.1.3.4 SELECTION OF SUPPORT SERVICES 110

9.1.3.5 ENSURING MARINE INTEGRITY 110

9.1.4 H2S EMISSION CONTROL PLANS 112

9.1.4.1 DETECTION AND ALARM SYSTEMS 112

9.1.4.2 VISUAL WARNING SIGNS 113

9.1.4.3 MUSTER STATION AND ESCAPE ROUTE 113

9.1.4.4 VENTILATION 113

9.1.4.5 H2S KICK CONTROL 113

9.2 DISASTER MANAGEMENT PLAN 114

9.2.1 PURPOSE & SCOPE OF THE PLAN 114

9.2.1.1 UPDATING AND EXERCISES 115

9.2.1.2 DISASTER MANAGEMENT PREPAREDNESS 115

9.2.1.3 ON SCENE COORDINATOR 110

9.2.1.4 SITE CONTROL ROOM 116

9.2.1.5 COMMUNICATION 116

9.3 OIL SPILL RISK ASSESSMENT 117

9.3.1 OIL SPILL SCENARIOS 117

9.3.1.1 MARINE & COASTAL FEATURES SENSITIVE TO OIL SPILLS 117

9.3.1.2 ASSESSMENT OF RISKS DUE TO OIL SPILLS 118

9.3.1.3 OIL SPILL CONTINGENCY PLAN 118

9.3.1.4 PROJECT NEED & BENEFITS 124

CHAPTER 10 ENVIRONMENT MANAGEMENT PLAN 126

10.1 SELECTION OF DRILLING LOCATION AND NAVIGATIONAL

PATH WAYS 126

10.2 ATMOSPHERIC EMISSIONS 127

10.3 STORAGE AND HANDLING OF CHEMICALS AND SUPPLIES 127

10.4 MANAGEMENT OF DRILL CUTTINGS & DRILLING MUD 128

10.5 OILY WATER DISCHARGES AND OTHER WASTES 129

10.6 MANAGEMENT MANUAL 131

Sl.No. Page no.

10.7 MANAGEMENT SYSTEM PROCEDURES AND

DOCUMENTATION 132

Chapter 11 ORGANISATIONAL STRUCTURE AND IMPLEMENTATION

FRAME WORK 135

11.1 CAPITAL AND RECURRING COST FOR ENV. POLLUTION

CONTROL MEASURES 136

11.2 DISCLOSURES OF CONSULTANTS ENGAGED 136

11.3 EIA CONSULTANT ENGAGED 136

11.4 AGENCY ENGAGED FOR CRZ MAPPING 136

Chapter 12 BIBLIOGRAPHY 137

ANNEXURE-I TOR ISSUED BY MOEF&CC FOR THE NELP VII BLOCK MB-

OSN-2005/3 (SCANNED COPY) 142

ANNEXURE-II LETTER FROM DGH (SCANNED COPY) 150

ANNEXURE-III EQUIPMENT AND APPLICABLE STANDARDS 151

ANNEXURE-IV COMPARATIVE ECOTOXICITIES 154

Team from Project Proponent

EIA Sector

Number as per

NABET

2

Name of

Sector

Offshore & On land oil & gas

exploration, development &

production

EIA Coordinator

Name Dr. J.S.Sharma

Signature & Date

Period of Involvement October, 2015 onwards

Contact Information ONGC, CHSE, SCOPE Minar, 8th Floor, Laxmi Nagar,

New Delhi. Mobile:9868282230

Functional Area Experts

Sl.

No.

Name Functional Area

1. Dr. J.S.Sharma I. Air Pollution Control II. Water Pollution

III. Solid and Hazardous Waste IV. Air Quality Modelling

2 Mr. Ravi Misra,DGM(Geology) i. Geology ii. Hydrology

3 Dr. (Mrs) Archana Yadav Ecology and biodiversity

4 Mr. D. K. Trivedi,CE(P) Noise & vibration

5 Mr. Amlan Chakraborty,CE(Mech.) Risk & Hazards

6 Mr. H J Godbole, EE(Env.Engg.) Water Pollution

7 Mrs. Vineeta Kumari Sattawan Ecology and biodiversity as

Associate

8 Sh S K Lijhara Assisted as EIA Coordinator

Executive summary

ONGC has acquired NELP-VII block MB-OSN-2005/3 as operator with 70% PI while the rest

30% is retained by Essar Energy. The exploratory block MB-OSN-2005/3 was initially awarded to M/s

Essar Energy as Operator along with M/s Noble Energy with 50% PI each. However, M/s Noble Energy

backed out from the consortium therefore, M/s Essar Energy became the sole operator with 100% PI.

Later on, a firm-out agreement was signed between ONGC and Essar Energy on 24.12.2014 whereby

ONGC acquired NELP- block MB-OSN-2005/3 during the phase-II (04.08.2013 to 03.02.2016) of

operation with commitment of drilling one exploratory well as per the Minimum Work Programme (MWP).

The NELP-VII Block MB-OSN-2005/3 is located in the southwest of the Mumbai High-DCS

platform of Mumbai Offshore Basin, having an area of 1685 km2. Two wells, viz., SM-1-1 and SM-1-2

were drilled in the early nineties on the western flank of the block. It is approximately 44 km north-north-

east due SM-86 structure and about 80 Km north-west of D-1 hydrocarbon bearing structure. Deep water

nomination block BB-OS-DW-1 lies in the west of the block. The block is located in the shallow water

western offshore

The Production Sharing Contract (PSC) requires to conduct EIA studies and obtain its approval

from MoEF&CC. It is also emphasized in the PSC that the contractor shall conduct its petroleum

operations with due regard to and concern with respect to protection of the environment and conservation

of natural resources.

The area in and around the block had been extensively explored for hydrocarbon prospectivity.

To assess the baseline environmental status of the block, data from the adjacent area and wells have

been gathered and analysed by IPSHEM, ONGC, Goa. In addition, secondary information on

meteorology, biological characteristics of nearest beaches and coastal area and ocean hydrography have

been obtained from literature reviews and information available in the public domain.

The baseline data comprise of chemical characteristics, dissolved oxygen, nutrients like nitrate,

nitrite, phosphate and silicate and presented briefly in the following lines.

Temperature is found to vary from 26.2-28.3 °C respectively, the average being 27.31 °C. The

surface layer showed higher temperature at all the sampling stations varying from 26.0-26.9 °C The

observed range of temperature variation is well in normal limits for the coastal waters.

pH is found to vary from 7.12-8.30 the average pH values were detected of 7.78 and 7.67

respectively. No particular trend is followed regarding the distribution of pH, though all the observed pH

values are well within normal limits.

Salinity around the points of observation depict variation from 31.5-37.5 PSU the average salinity

values were detected of 34.4 PSU and 35.57 PSU respectively. The observed salinity values are similar

to those observed at the reference stations and the values are well within acceptable limits.

Turbidity is found to varfy from 4.6 – 16.8 NTU and 3.4 – 17.4 NTU respectively and an average

turbidity values were detected of 10.31 NTU and 9.02 NTU respectively. The variation of turbidity has

followed no trend and the observed turbidity indicate normal values for the seawater at the site.

TDS vary from 10-38 mg/l and 9-34 mg/l respectively with an average of 24.98 mg/L and 18.63

mg/L respectively. However comparing the values with reference point; disturbance of operational activity

cannot be concluded. The observed values are within normal limits for the coastal seawater

Dissolved Oxygen (DO) concentrations are considered to be very vital parameter to assess the

health of the marine environment especially where exploration and production activities are in progress.

DO variation from 3.24-5.38 mg/l and 3.25-5.34 mg/l respectively with an average 4.42 mg/l. It is observed

that all obtained values are most similar to the values obtained at reference station values and well within

acceptable limits for the coastal seawater.

Nutrients - Phosphate– Phosphorus (PP)’s variation is from 0.042–0.84 μmol/l and 0.045–0.75

μmol/l respectively with an average PP values at 0.21 μmol/l. The vertical variation of phosphates at these

stations showed no regular trend of phosphorous. The values observed however are normal for the

coastal seawater.

Nitrite–Nitrogen have been found to vary within the range of 0.008 – 0.026 μmol/l with an average

value 0.017 μmol/l. The Nitrite – Nitrogen values follow no particular trend and they are similar at all the

observation columns. The values observed are well within normal acceptable limits. Nitrate – Nitrogen,

on the other hand, vary from 0.015 – 4.5 μmol/l. The Nitrate – Nitrogen values follows no particular trends

and values are at lower side. The values are within normal acceptable limits.

Silicates is found to vary from 0.12-0.57 μmol/L and 0.16-0.45 μmol/L respectively. The observed

values are normal for the coastal seawater. Petroleum Hydrocarbons (PHC) values come under non

detection level. The distribution of PHC in the sediment samples has shown minute contamination, though

all observed valued values are acceptable limits.

Sediment Quality - The Total Phosphorous and Total Nitrogen’s concentration was measured in

the sediment samples has shown variation from 19.7—40.2 μg/g, the average being 29.2 μg/g and 25.2

μg/g respectively. The Total Organic Carbon’s concentration was measured to vary from 1.9% to 4.7%

and 2.0% to 4.2% respectively and an average values were detected of 3.0% and 3.0%μg/g respectively.

The PHC’s concentration in the sediment samples has shown variation from 45.62– 86.74 mg/g with an

average of 64.055 mg/g. The values are within acceptable limits. The texture of sediment samples has

been analyzed and it has been observed that the composition of clay varies from 30% -42% with average

value of 36.71%.

The meteorological and climatological environment has been assessed from secondary data

available in the public domain and scouting the literature. The average rainfall in the Arabian sea is of the

order of 1-2 mm /day while the mean wind speed lies in the range of 6.1 to 6.8 m/sec. Maximum and

minimum value of mean air temperature in the Arabian Sea is of the order of 30.2 ºC and 24.4 ºC,

respectively. Mean air temperature of the area of exploratory block lies in the range of 26.5 ºC to 27.5 ºC.

It is observed that monthly frequency of depression, cyclonic storm and severe cyclonic storm in the

Arabian Sea was highest for June followed by November and May in a year.

In addition, potential impacts on the environment have been assessed and duly incorporated in

the report. ONGC has an elaborate Disaster Management Programme (DMP) with an exhaustive manual

of disaster management methodologies that are capable of taking care of an eventuality of any magnitude

with the primal objective to impact the environment the least. Activities related to exploratory drilling,

namely, operational discharges like sanitary waste water, food waste and residuals, washing fluids (deck

drainage, rig floor washing etc.), cooling water, non-routine discharges that may be caused by ballast

water, chemical spills has the potential to impact marine water quality.

ONGC is committed to protect the environment through improving the effectiveness of

management and reporting systems and ensuring the reduction of local environmental impact from

operations by improving environmental performance and implementing initiatives for the conservation of

biodiversity and the resource recovery and reuse. ONGC places high emphasis on health and safety

aspects of workers and staff and will ensure that all activities will be conducted in a safe and skillful

manner with staff appropriately trained and equipment maintained in safe condition. ONGCs QHSE

management system entails continuous monitoring to be carried out for various aspects of the project,

environmental, safety and health impacts and the performance of EMP implementation.

Pre-drill EIA for the NELP block MB-OSN-2005/3

1

Chapter -1

INTRODUCTION

1.1 PURPOSE

The exploratory block MB-OSN-2005/3 was awarded to M/s Essar Energy as Operator along

with M/s Noble Energy with 50% PI each. Afterward, M/s Noble Energy backed out from the consortium

therefore, M/s Essar Energy became the sole operator with 100% PI.

Later on, a firm-out agreement was signed between ONGC and Essar Energy on 24.12.2014

whereby ONGC acquired NELP- block MB-OSN-2005/3 as operator with 70% PI while Essar Energy with

30% PI. As per the Minimum Work Programme (MWP), presently phase-II is going on from 04.08.2013

to 03.02.2016 with commitment of drilling one exploratory well. In this regard, EC is required at the earliest

possible to start the drilling operation in time to complete the exploratory well before the due date i.e.

03.02.2016 for which EIA study of the block is required. The NELP-VII Block MB-OSN-2005/3 is located

in the southwest of the Mumbai High-DCS platform of Mumbai Offshore Basin, having an area of 1685

sq. km. The water depth within 3D seismic area, where prospects are likely to be drilled, ranges from 90

m to 100 m. Well SM-1-2 is near western boundary of the block. It is approximately 44 Km north of SM-

86 structure and about 80 Km north-west of D-1 hydrocarbon bearing structure. Deep water nomination

block BB-OS-DW-1 lies in the west of the block. The block is located in the shallow water area. (Fig-1.1:

Location Map).

It may be emphasized that the EIA notification 2006, which requires prior Environmental

Clearance from the Ministry of Environment & Forest (MOEF&CC), before carrying out exploratory

drilling, is not applicable in the block as the block is located beyond territorial waters (beyond the

stipulated 12 nautical miles). However, the Production Sharing Contract (PSC) requires conducting of

EIA studies and obtaining its approval from MOEF&CC. It is also emphasized in the PSC that the

contractor shall conduct its petroleum operations with due regard to and concern with respect to

protection of the environment and conservation of natural resources.

ONGC had applied for EC in Form-I to MoEF&CC on 11.06.2015. The project was discussed

in 44th Reconstituted Expert Appraisal Committee (Industry-2) on 21.07.2015 Terms of Reference (ToR)

for the preparation of Environmental Impact Assessment has been issued by MoEF&CC to ONGC vide

F NoJ-11011/171/2015- IA II (I) dated 31.08.2015 (Annexure-I).


2

Fig. 1.1: Location Map showing position of NELP Block MB-OSN-2005/3

1.2 IDENTIFICATION OF THE PROJECT PROPONENT & THE PROJECT

ONGC is a premier national hydrocarbon E & P company having Maharatna status. ONGC

was founded in the year 1956 to power a new born republic making rapid strides towards growth and

development. Discovering 6 (six) out of 7 (seven) oil and gas producing basins, adding 8.6 billion tons of

oil and gas reserves, it has led India’s quest for national energy security. Today ONGC is the world’s

No.3 Exploration and Production Company. With a recoverable reserve of 2.0 billion tons of oil equivalent,

ONGC’s daily production of over 1.22 million barrels per day contributes over 69% of India’s domestic oil

equivalent production. It is the country’s trust in our vision that makes us largest exploration and mining

lease holder in the country. Fuelled by the desire to build a strong energy foundation for tomorrow, we

have gone beyond the seven seas. ONGC’s wholly owned subsidiary ONGC Videsh Ltd(OVL) is the


3

nation’s biggest E&P multinational, managing 35 overseas hydrocarbon properties in 16 countries, with

a cumulative investment of over US$22 billion. Winning hearts and awards world over, ONGC is one of

the fortune World Most Admired Companies of 2014. ONGC is the Top Energy Company of India as per

the coveted Platts Top 250 Global Energy Company ranking 2014. In FY 2014-15, ONGC made 22 oil

and gas discoveries (in the areas operated by ONGC). Of these, 10 discoveries were made in new

prospects whereas 12 were new pool discoveries. Out of 22 discoveries, 12 discoveries were made in

onshore areas; 7 in shallow water offshore and 3 were in deep-water. 7 were oil discoveries, 6 were oil

& gas bearing and 9 were gas discoveries. In FY 2014-15, ONGC achieved crude oil production of 22.264

MMT. (Excluding JV share). ONGC’s JV share of crude oil production was 3.679 MMT. Thus total crude

oil production (including condensate) was 25.943 MMT (excludes ONGC Videsh share). In FY 2014-15,

ONGC achieved Natural Gas production of 22.02 BCM. (excluding JV share). ONGC’s JV share of natural

gas production was 1.50 BCM. Thus total natural gas production was 23.52 BCM (excludes ONGC

Videsh share). During the year 2014-15, ONGC acquired 605.9 GLK/LK of 2D and 9176.5 SKM of 3D

seismic data. A total of 371 wells were drilled out of which 103 were exploratory wells and 268

development wells. ONGC accreted Initial in place hydrocarbon reserves of 215.65 MMToe & Ultimate

reserves of 70.98 MMToe (3P).

As for as oil discoveries done by ONGC is concerned, it has made 14 oil and gas discoveries

in domestic fields (operated by ONGC). Out of these, 12 discoveries were made in the new prospects

whereas 10 were new pool discoveries. Nine discoveries were made in NELP blocks and thirteen in the

nomination blocks.

Mangalore Refinery & Petrochemical Ltd. (MRPL) and ONGC Videsh Limited (OVL) are two

fully owned direct subsidiary of ONGC. OVL is the biggest Indian multinational, with 40 oil & Gas projects

(9 of them producing) in 16 countries i.e. Vietnam, Sudan, Iraq, Iran, Russia, Myanmar, Libya, Cuba,

Colombia, Nigeria, Nigeria Sao Time JDZ, Egypt, Brazil, Syria and Venezuela. OVL recorded highest-

ever Net Profit of Rs. 39,291 million. ONGC Videsh achieved Oil Production of 5.533 MMT & Natural Gas

production of 3.341 BCM for FY 2014-15.

On an average, ONGC drills about 20 exploratory wells every year in the Arabian Sea. The

Western Offshore area has been the main contributor of domestic hydrocarbon production in India. This

endeavor will continue in the Block MB-OSN-2005/3 which is located in the Mumbai Offshore, having an

area of 1685km2. The cost of drilling a well is estimated at approximately ₹ 124 crores. The project block

is located in Arabian Sea due southwest off the state of Maharashtra.

The only well which will be drilled by the ONGC is in this block is about ~138 nm from the

coast. Offshore rigs (MODU) will be deployed for the proposed drilling. ONGC has its centralized

warehouse/ stores at Nhava. Accordingly, all the material will be brought to the site from Nhava supply


4

base by sea route through Offshore Supply Vessel (OSVs). However, the personnel will be transported

to the rig by helicopters from the Juhu Helibase, Mumbai.

1.3 SCOPE OF STUDY

Terms of Reference (ToR) assigned by MoEF&CC would be the basis of scope of EIA study along with

understanding of the project and its implication, assessing the marine physical environment where the project

would be located and probable interactions that are expected to occur as a result of execution of the project.

The scope of work includes:

Review of regulatory and institutional framework to ensure that ONGC is aware of regulatory

obligations and make compliance while undertaking project activities.

Collate and analyze primary and secondary data on environmental components like

meteorology, marine water quality, levels of pollution, marine and coastal ecology, etc.

Assess potential environmental impacts that may arise as a result of the project and

evaluate them.

Table 1.2.1: Project at Glance

Sl. No. Parameter Particulars

1 Area Shallow offshore due south and southwest Mumbai, 1685 km2

2 No. of Wells 01

3 Depth of the wells (m) 2500 m

4 Water Depth (Bathymetry) (m) ~ 90 to ~ 100 m

5 Distance from the Coast (m) 138 nm

6 Water Consumption 40 m3/day

7 HSD consumption 60 kl / day

8 Drill Cuttings 3 – 8 m3 / day, i.e., about 20 – 50 bbls / day

9 Cost of the Project ₹ 124 crores

10 Sensitive Areas No sensitive or legally protected areas lie in the close vicinity of the block which is located about 250 km southwest off the coast of Mumbai, Maharashtra.


5

Chapter-2

Terms of reference

2.1 POINTWISE COMPLIANCE OF TOR:

Terms of Reference (ToR) for the preparation of Environmental Impact Assessment issued

by MoEF to ONGC vide F No. J-11011/171/2015-IA-II (I) dated 31st August 2015 has been duly

addressed in EIA-EMP Report. Summary of the same is tabulated below:

TABLE 2.1: COMPLIANCE WITH TERMS OF REFERENCE PROVIDED BY 44th EXPERT

APPRAISAL COMMITTEE (INDUSTRY-2) OF MOEF

Sl Points of TOR Issues Addressed In EIA-EMP and RA Report

1 Executive summary of the

project

Executive summary included in EIA report of the project (p.

i-iii)

2 No. of exploratory wells for

which environmental

clearance is accorded and

no. of new wells proposed

during expansion. Status and

no. of the wells which are

completed and closed.

Environment Clearance has not been accorded so far this

block. ONGC plans to drill 1 (one) exploratory well in this

block.

3 Project Description and

Project Benefits;

Initially the exploratory block MB-OSN-2005/3 was

awarded to M/s Essar Energy as operator along with M/s

Noble Energy with 50% PI each. However, M/s Noble

Energy left the consortium thereby M/s Essar Energy was

having 100% PI with it. Later, a firm-out agreement was

signed between ONGC and Essar Energy on 24.12.2014

whereby ONGC agreed to acquiring the NELP-VII block

MB-OSN-2005/3 as operator with 70% PI while Essar

Energy would retain 30% PI. As per the Minimum Work

Programme (MWP), during the Phase-II, from 04.08.2013

to 03.02.2016, it is committed to drill one exploratory well in

the block. The block comprises of an area of 1685 Km2. It is

a shallow water offshore block in the West Coast of India.

(Chapter 3, p. 10-23)

4 Cost of project and period of

completion

₹. 124 crores, Time of completion : 4-5 Months


6

5 Employment to generated Well will be drilled hiring a Jackup or a Floater (MODU)

drilling rig.

6 Distance from coast line The block is located on the continental shelf west off the

coast of Mumbai about 250 km from the coast.

7 Details of sensitive areas

such as coral reef, marine

water park, sanctuary and

any other eco-sensitive area.

No sensitive areas such as coral reef, marine water park,

sanctuary and any other eco-sensitive area lie within 10 km

from the block boundary.

8 Recommendation of SCZMA/

CRZ Clearance as per CRZ

notification dated 6th January

2011 (if applicable).

CRZ notification is not applicable on this project, as the

block is beyond territorial waters. (Section 3.2.1, p.14)

9 Details of support

infrastructure and vessel in

study area.

Operational personnel shall be commuted to and fro to the

rig by helicopter from the service base at Juhu-Helipad,

Mumbai. The material will be transported to the rig by OSVs

from the Nhaba Supply base-the frequency of OSVs shall

depend on the actual requirement, never more than once

per day.

10 Climatology and meteorology

including wind speed, wave

and currents, rainfall etc.

Section 3.7, p. 23 – Climatology and Meteorology of

Mumbai Offshore.

11 Details on establishment of

Base line on air quality of

areas immediately affected

by the exploratory drilling and

also particularly with

reference to hydrogen

sulphide, sulphur dioxide

NOx and background levels

hydrocarbons and VOCs.

Baseline data on marine water quality generated by

analysis of 23 water samples gathered in and around the

project area and the probable drilling location. (Chapter 4,

p.30).

12 Details on estimation and

computation of air emissions

(such as nitrogen oxide,

sulphur dioxides, carbon

mono oxides, hydrocarbons,

VOC, etc.) resulting from

flaring, DG set, combustion

etc. during all project phases.

(Chapter 4, p.30).


7

13 Base line data collection for

surface water for one season

leaving the monsoon season

within one Km for each

exploratory well, particularly

in respect of oil content in

water sample and sediments

sample.

Baseline data on marine water quality generated by

analysis of 23 water samples gathered in and around the

project area and the probable drilling location. (Chapter 4,

p.30).

14 Fisheries study w.e.t.

benthos and marine organic

material and coastal

fisheries.

(Chapter 4, p. 30).

15 Source of fresh water.

Detailed water balance ,

waste water generation and

discharge.

The average daily water consumption will be about 40

m3/day and will be supplied from Nhava supply base of

ONGC. Wastewater generation from the drilling well is

expected to be around 10 m3/day. The dirty oil from bilge

fluid will be periodically sent to shore in drums or special

containers by supply vessels deployed for the purpose.

(Section 3.4.2; p.19, Section 3.4.3, p.20-Waste Water

Generation and Discharge)

16 Noise abatement measures

and measures to minimize

disturbance due to light and

visual intrusions in case of

project site closed to coast.

Discussed under Section 5.1.2, p.82

17 Procedure for handling oily

water discharges from deck

washing, drainage systems,

bilges etc.

Section 10.5 - Oily Water Discharges and Other Wastes,

p. 129

18 Procedure for preventing

spills and spill contingency

plans

Section 10.5, p. 129

Chapter 11, p.135

19 Procedure for treatment and

disposal of produced water

During well testing oil is stored in storage tanks, gas is

flared, and water is discharged to sea after treatment. Oil is

transported to base facility.(Section 3.4.3,p.21)

20 Procedure for sewage

treatment and disposal and

also for kitchen waste

disposal.

Section 6.4 - Sewage Treatment and Disposal, p.86


8

21 Details on solid waste

management drill cutting,

drilling mud and oily sludge

produced sand, radioactive

materials, other hazardous

materials, etc including its

handling options during all

project phases.

Section 6.2, p.85 – Membership of Common Disposal

facilities.

The disposal of the drill cuttings will be conforming to the

guidelines pertaining to the “Disposal of Drill Cuttings and

Drilling Fluids for Offshore Installations” provided by the

Ministry of Environment & Forests (MoEF) G.S.R. 546(E)

August 2005.

22 Storage of chemicals on site Section 3.4.4 – Chemical Storage at Rig, p-21

23 Commitment for the use of

WBM and synthetic oil based

mud in special case

ONGC is committed to using only Water Based Mud (WBM)

for the offshore exploratory drilling operations. However,

synthetic oil based mud (SOBM) will be used to combat

specific hole problems. Refer to Mud System and Cuttings,

p.18.

24 Details of blowout preventer

installation

It is standard oil-well drilling practices to install BOP at the

well head (section 3.1-Technology and Process

Description, p.17).

25 Risk assessment and

mitigation measures

including whether any

independent reviews of well

design, construction and

proper cementing and casing

practices have been followed

Risk assessment – Section 9.1, p.92

26 Handling of spent oils and oil

from well test operations.

Section 6.6 Handling of spent oil, p.87

Section 6.7 - Oil Handling From Well Test Operations, p.87

27 H2S emissions control plans,

if required

Section 9.1.4, p.112

28 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.

Section 10.7–Management System Procedure and

Documentation, p.132

29 Restoration plans and

measures to be taken for

decommissioning of the rig

After drilling and initial testing, if the well does not contain

commercial quantities of hydrocarbon, the site is

decommissioned to a safe and stable condition and


9

and restoration of on-shore

support facilities on land

restored. Open rock formations are sealed with cement

plugs to prevent upward migration of wellbore fluids. The

casing wellhead and the top joint of the casings are cut at

the ground level and capped with a cement plug. The

hazardous waste will be sent to authorize hazardous waste

disposal facility.

30 Documentary proof for

membership of common

disposal facilities, if required

The solid waste generated on the rig will be segregated and

stored in colour coded bags. The solid waste will be

transported back using support vessels or with the rig, to

the Nhava supply base of ONGC. At Nhava supply base the

segregated waste will be treated separately. Hazardous

waste, if any, will be sent to authorized hazardous waste

recyclers and disposal facility.(Section 6.2 – Membership of

Common Disposal Facilities, p.85)

31 Any litigation pending against

the project or any directions /

order passed by any Court of

Law against the project. If so,

details thereof.

Not Applicable.

32 Total capital and recurring

cost for environmental

pollution control measures.

Section 11.1, p.136 - Capital and Recurring Cost for

Environmental Pollution Control Measures


10

Chapter 3

PROJECT DESCRIPTION

3.1 TYPE OF THE PROJECT

Initially the exploratory block MB-OSN-2005/3 was awarded to M/s Essar Energy as Operator

along with M/s Noble Energy with 50% PI each. Due to withdrawal of M/s Noble Energy, M/s Essar Energy

was having 100% PI with it. Later on, a farm out agreement between ONGC and ESSAR for JV

partnership was signed on 24th December 2014 with ONGC as operator. The participating interest of

ONGC is 70% and for ESSAR 30%. Vide letter No. DGH/PSC/ (MB-OSN-2005/3)/Phase-

II/Assignments/2015 dated 28th April 2015, MOPNG has approved the proposed assignment of 70% to

ONGC and transfer of ownership (Letter from DGH: Annexure - II).

Geological Setup:

The Block MB-OSN-2005/3 falls in the Shelf Margin block of Mumbai Offshore Basin. Shelf

Margin is demarcated to the east by Paleocene shelf edge, to the west by West Margin basement arch,

to the north by Saurashtra Arch and to the south by Vengurla Arch. Major structural elements within the

block from north to south are Saurashtra low to the north, followed by Alibagh saddle to the south of it

(DCS platform and south Bombay low fall just to the east of it), Murud low, Mahabaleshwar high and

Rajapur low to the south. The shelf is characterized by NNW-SSE trending parallel sets of longitudinal

faults giving rise to series of horst-graben features.

Basement associated anticlinal highs of Paleocene-Eocene sequence and tilted fault blocks

of oligo-miocene section formed due to gravity slide are the two main structural styles in the block.

The generalized litho-stratigraphy (Fig. 3.1) of the shelf margin block is established based on

the information of the wells SM-1-1 and SM-1-2, following the framework of lithostratigraphic classification

of Mumbai offshore basin. In general the area received dominantly finer clastic of claystone and and

shale except for medium to thick carbonate deposits of Eocene and upper Miocene times which are

laterally less extensive.


11

Fig.3.1: Generalized stratigraphy of the Shelf margin area

3.2 LOCATION OF PROJECT

The initial 2D seismic interpretation indicates six probable locations for drilling wells as shown

in the Map at Fig. 3.2 and Fig. 3.3 given below. However, initially, only one well is to be drilled, out of

identified 6 prospects. The exact position of the well would be decided on the basis of 3D interpretation

of seismic data being acquired in the block.

Water depth and TD of well

Water depth (bathymetry map. Fig. 3.4) of the 3D area (within the block) where prospects are

identified and to be drilled, falls within the range of 90 m to 100 m. The total depth of the well to be drilled

will be 2500 m.


12

Fig.3.2: Tentative Prospects shown in 3D area

However, the tentative details of the well location is as follows:

Table 3.1 : Tentative details of the well location

Horizontal/Vertical Vertical well

Deep/Shallow Shallow water

Bathymetry 90-100 m

Target Depth 2500 m

Mud to be used Water based (SOBM if necessity arises)

Objective Mio-Pliocene sequences

Co-ordinates of location X: 638204.80

Y: 2092770.06


13

Fig. 3.3: Block Map with tentative prospects.

Fig-3.4 Map indicating coastal land near the block MB-OSN-2005/3

The geographical coordinates of the boundary of the NELP exploratory block MB-OSN-2005/3 are

provided in the Table 3.2.

MAP INDICATING COASTAL LAND NEAR BLOCK MB-OSN-2005/3

MAP SHOWING THE BAATHYMETRY OF THE AREA


14

TABLE 3.2.: Geographical coordinates of Block MB-OSN-2005/3.

Longitude Latitude

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

A 70 05 11.27 19 04 16.54

B 70 20 17.00 19 06 56.00

C 70 45 53.78 18 30 17.00

D 70 35 00.00 18 30 17.00

E 70 35 00.00 18 40 00.00

F 70 21 07.13 18 40 00.00

A 70 05 11.27 19 04 16.54

3.2.1 CRZ Regulation Applicability

The block MB-OSN-2005/3 is located beyond 12 nautical miles from the coast line, CRZ

regulations, therefore, is not applicable.

3.2.2 DRILLING WELL LOCATION

One exploratory well RMBSO53NAA-A with geographical coordinates X: 638204.80 Y:

2092770.06 has been planned to be drilled in the NELP-VII block MB OSN-2005/3 as per the committed

MWP. Since the block lie in the shallow offshore at a distance of over 250 km southwest off the coast of

Mumbai, the stipulation and the guidelines by MoEF&CC that no drilling within 1 km from coastline i.e.

Low Tide Line (LTL) is not applicable in the case.

3.3 PROPOSED PROJECT SCHEDULE FOR APPROVAL AND IMPLEMENTATION

The project activities for the proposed offshore drilling processes have been divided into three

phases- Mobilization of drilling rig, Drilling and finally Decommissioning. Drilling activity under normal

conditions would continue for about 40-60 days to drill one well. Casing will be lowered in the well drilled

and tested by perforation if indications of hydrocarbons are noticed. The well will be sealed for further

development if the prospect so discovered is found to be a successful hydrocarbon bearing structure.

3.4 TECHNOLOGY AND PROCESS DESCRIPTION:

The different phases, as mentioned above, for the exploratory drilling are

Mobilization of the drilling rigs

Drilling and testing

Decommissioning

These phases are explained in the subsequent sections. A flow chart describing the major phases of

‘Oil exploration’ is sketched in the Fig. 3.5.


15

Drilling and testing phase

Seismic data acquisition is the initial process of Exploitation of hydrocarbons followed by

processing and interpretation for identification of viable prospect. The prospect so identified is required

to be probed by drilling to ascertain the accumulation and, in the eventuality, the extent of the prospect.

Wells are drilled, offshore or onshore, using a rig and ancillary tools and equipment.

There are two basic categories of offshore drilling rigs; those that can be moved from place

to place, allowing for drilling in multiple locations, MODU (Mobile Offshore Drilling Unit), and those rigs

that are temporarily or permanently placed on a fixed platform (Platform Rigs). In the present case, the

water depth of proposed location is about 90-100 meter therefore, drilling will be done by deploying a

floater rig where in a rig is mounted on a ship. ONGC will use Mobile Offshore Drilling Unit (Floater/Jack

up Rig, Fig. 3.6, Fig. 3.7) for drilling the well.

Fig 3.5: Flow chart describing in nutshell the ‘Oil Exploration Process’


16

Fig. 3.6: Typical picture of jack-up rig

Fig 3.7: Typical picture of floater rig

Initial Well Construction

Offshore wells are drilled in sections, with the diameter of each section decreasing with

increasing depth. Lengths and diameters of each section are determined prior to drilling and depend on

geological conditions through which the well is to be drilled. The conduit or pipe section will be set in

place by jetting operations. Drilling starts with spudding a hole of diameter 26" on the sea bed, followed

by lining it with a metal casing of 20". The above structural section is likely to be drilled using sea water.

Next hole will be of 17-1/2" diameter and casing will be 13-3/8". Further hole will be of 12-1/2" diameter

with 9-5/8" casing.


17

Well head equipment is installed thereafter followed by marine riser including the Blowout

Preventer (BOP, Fig. 3.8). The blowout preventer is a large underwater assembly of control valve that

prevents high pressure from the well escaping through the water and oil column into the surface at the

derrick floor. The release of this pressure is called a “blowout” and can result in an explosion and could

cause large scale damage to the environment. If a blowout were to occur with a BOP in place, giant

valves inside it seal off the well, containing any excessive pressure and putting it back into the ground.

Maintaining the BOP and continually testing it is a very high priority for both ONGC and its drilling

contractor.

The BOP is placed on top of the wellhead (the top of the well), which is why it is important to

make sure the casing is properly cemented in place. A marine riser is a type of offshore drilling tool that

is used as a temporary extension connecting the oil well to the rig.

Picture from Google images

Fig. 3.8: A Typical drawing of a BOP (Blow Out Preventer)

As drill pipe is lowered down through the marine riser, through the BOP, into the wellhead,

and then further down into the well, drill fluid or mud (fluid that helps clear the rock bits or “cuttings” that

are being chipped away when drilled) is pumped back up through the pipe annulus and out through the

drill bit. The mud eventually circulates around up through the marine riser and back to the surface of the

oil rig. As each section is drilled, casing is run and cemented into place ready for drilling the next smaller

diameter section. Operations continue in this way until target depth is reached.


18

Mud System and Cuttings

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

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

After separation of drill cuttings /solids through solids control equipment, the mud is circulated back.

Drilling fluid is essential to drilling operations in order to:

Control down-hole pressure

Lift soil/rock cuttings from the borehole bottom and carry them to settling pit

Prevent cuttings to settle rapidly.

Prevent caving

Seal the borehole wall to reduce fluid loss. (Formation of filter cake)

Cool and clean the drill bit and lubricate drill bit, bearings, mud pumps and drill pipes

ONGC is committed to using Water Based Mud (WBM) for the offshore exploratory drilling

operations. However, synthetic oil based mud (SOBM) will be used to address specific down-hole issues,

if so warranted. Otherwise, keeping in view the environmental factors in the backdrop, only water based

mud is proposed to be used in the drilling the exploratory wells in the block. Water-based mud is made

up of clay (bentonite) and water; it may include barite, a heavy mineral to increase specific gravity of the

mud system. Chemical additives are mixed in to stabilize the drilling fluid during use, and to reduce

corrosion and bacterial activity. Chemical additives viz. glycols and salts may be used in conjunction to

mitigate potential problems related to hydrate formation.

The mud is subjected to continuous testing for its physical parameters, namely, density,

viscosity, yield point, water loss, pH value, etc. to ensure that drilling operations are successful and

continued without any down-hole complication. The mud will be prepared onsite (drill location) using

centrifugal pumps, hoppers and treatment tanks.

Drill-cuttings that circulate back to the surface will be separated from drilling mud using control

equipment comprising of linear motion vibrating screens called shale shakers, hydro-cyclones (including

de-sanders and de-silters), and centrifuges to mechanically separate cuttings from the mud. Once

cuttings have been separated, drilling fluid will be processed or reused after further treatment. The total

mud-circulation is depicted in a sketch in Fig. 3.9.

The time taken to drill a bore hole depends on the depth of the hydrocarbon bearing formation

and the geological conditions, but it is commonly of the order of 50 to 60 days. Where hydrocarbon

formations is found, initial well tests—possibly lasting for another 20 to 30 days—are conducted to

establish flow rates and formation pressure.


19

Fig. 3.9: Typical drilling fluid circulation system

After drilling and initial testing, the rig is usually dismantled and moved to the next site. If the

exploratory drilling has discovered commercial quantities of hydrocarbons, a wellhead valve assembly

may be stalled. If the well does not contain commercial quantities of hydrocarbon, the site is

decommissioned to a safe and stable condition and restored to its original state. Open rock formations

are sealed with cement plugs to prevent upward migration of fluids. The casing wellhead and the top joint

of the casings are cut at the ground level and capped with a cement plug.

3.4.1. Source of Water

Water requirement in a drilling rig is mainly meant for preparation of drilling mud apart from

washings and domestic use. The average daily water consumption is of the order of 40 m3/day will be

drawn from Nhava supply base of ONGC (which is a main material supply base for offshore installations

of western region) along with other materials through sea route. Nhava supply base of ONGC receives

water from Industrial Development Corporation of Maharashtra Limited (CIDCO).

3.4.2. Water Usage Plan

The average daily water consumption is about 40 m3/day including water requirement for mud

preparation, washing and domestic activities. Wastewater generation from the proposed drilling activity

is from domestic activity @ 80 percent of the domestic water requirement and from washing @100

percent of the washing water requirement. Thus, wastewater generation from the drilling well is expected

to be 9 m3/day (Table 3.3).


20

TABLE 3.3: WATER USAGE PLAN

Sr. No. Particulars Water requirement (m3/day)

Water Requirement

1 Mud preparation 20

2 Washing activities 5

3 Shale Shaker 10

4 Domestic purpose 5

Total water requirement 40

Wastewater generation

1 Domestic activity 4

2 Washing 5

Total Wastewater Generation 9

Typical drill rig module (schematic) is shown in figure below.

Fig. 3.10: A sketch of a typical drilling rig module

3.4.3. Wastewater Generation & Discharge

Waste water generated at the rig will be of three types and its disposal methodologies are

explained in the subsequent sections. The International Convention for the Prevention of Pollution from

Ships (MARPOL) is the primary regulations/ guidelines on prevention of pollution of the marine

environment by ships. The Convention includes regulations aimed at preventing and minimizing pollution

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


21

Bilge Fluids

Bilge fluids are a mix of sea water, petroleum products and other brackish material that settles

to the bottom of a ship. The collection and disposal system for this fluid will be done in compliance with

the International Convention for Prevention of Pollution from Ships, 1973 as modified by the protocol of

1978 (MARPOL 73/78). The rig will be having provision to collect bilge fluids into a sludge tank and then

to a water/oil separator. Separated oil will then be diverted into "dirty oil" tank, where exhaust oil from

engine lubricant change is collected. The dirty oil will be periodically sent to shore in drums or special

containers by supply vessels. Separated water can be directly discharged overboard, provided that oil

content does not exceed 15 ppm as per MARPOL standards.

Deck Drainage

Drainage water generated from precipitation or routine operations, such as deck, rig floor and

equipment cleaning will be routed to separate drainage systems on the rig. This includes drainage water

from process/non-process areas that could be contaminated with oil. These waste fluids will be collected

by gravity in a tank and subsequently pumped into tanks installed below the main deck. The tank will be

periodically emptied, pumping waste fluid to the supply vessel for shipment to shore. Waste water,

wherever feasible, can be recycled to condition new mud and hence may be connected to the mud tanks

circulating system.

Grey and Black Water

Grey and Black Water is generated from showers, toilets, laundry and kitchen facilities on the

rig and will primarily contain waste material, paper, soap, etc. Rig operations will typically result in the

generation of sewage and wastes. Once collected through headers, they will be passed through a sewage

treatment plant (STP). The wastes will then be passed through a screen of less than 25 mm diameter

and an extended aeration system prior to their discharge into the marine environment. Sewerage

treatment on-site will be carried out in compliance with MARPOL 73/78 requirements.

3.4.4. Chemical Requirements and their storage at rig

Chemicals are required for preparation of WBM, giving the drilling mud the desired

characteristics to facilitate drilling at different depths. A variety of drilling chemicals and additives are

stored on the drilling rig with storage places clearly marked with safe operating facilities and practices.

Some of the common drilling and cementing fluid, chemicals likely to be used during drilling includes

cement, surfactants, de-foamers, lignin, inorganic salts, bentonite and barite, etc. as elucidated in the

Table 3.4.


22

TABLE 3.4: CHEMICALS USED FOR PREPARATION OF DRILLING FLUIDS

S. No. Name of Chemical S. No. Name of Chemical

1 BARYTES 21 MOD. GUAR GUM

2 BENTONITE 22 PAC-LV

3 BIOCIDE 23 PAC-RG

4 CAL. CARB, COARSE 24 PGS

5 LIME STONE POWDER (Marble) 25 PHPA

6 CAL. CARB, MICRONISED 26 POT. CHLORIDE

7 CAL.CHLORIDE 27 RESINATED LIGNITE

8 CAUSTIC SODA 28 SAW DUST

9 CITRIC ACID 29 SODIUM BICARBONATE

10 CMC 30 SODA ASH

11 COMMON SALT 31 SP. FLUID (N.W.)

12 DEFOAMER 32 SP. FLUID (W)

13 DRILLING DETERGENT 33 SUL. ASPHALT

14 E.P. LUBE 34 THERMOGEL

15 GLYCERENE 35 WALNUT SHELL

16 HEC 36 XC-POLYMER

17 HYDRATED LIME 37 ZINC CARBONATE

18 IRONITE SPONGE 38 GLYCOL

19 LIGNITE 39 SOBM

20 MICA FLAKES

3.5. LITIGATIONS & COURT DIRECTIONS / ORDERS

There is no litigation pending against the project or any directions/order passed by any Court

of Law against the project. The project has been awarded to ONGC (70%) as the operator in partnership

with Essar Energy (30%) by the Ministry of Petroleum and Natural Gas (MoPNG), Govt. of India under

NELP VII.

3.6. ASSESSMENT (FOR RISK OF TECHNOLOGICAL FAILURE) OF NEW AND UNTESTED TECHNOLOGY

Over five decades of its existence ONGC has grown to be one of the largest E&P companies

in the world in terms of reserves and production. ONGC as an integrated Oil & Gas Corporate has

developed in-house capability in all aspects of exploration and production business, i.e., Acquisition,


23

Processing and Interpretation (API) of Seismic data, drilling, work-over and well stimulation operations,

engineering and construction, production, processing, refining, transportation, marketing, applied R&D

and training, etc.

ONGC has planned to use Floater Drillship type mobile offshore drilling unit on hire-contract

basis for the Block MB-OSN-2005/3. The drilling technology and process to be used by ONGC, as

described in Section 3.4, is well established in Indian conditions. ONGC has used this technology and

process in many of its offshore exploration and drilling projects. No new or untested technology will be

used in the present case of drilling in MB-OSN-2005-3. ONGC generally use SOPs that are tested and

are used worldwide. The rigs to be used in the proposed exploratory block will be hired globally from

experienced vendors to ensure standard tested technologies. Thus the risk of technological failure of new

and untested technology does not arise.

3.7 Climatology & Meteorology of the Arabian Sea

Climate and meteorology of a place can play an important role in the implementation of any

developmental project. Meteorology (weather and climate) plays a key role in understanding local air

quality as there is an essential relationship between meteorology and atmospheric dispersion involving

the wind speed/direction, stability class and other factors. The block falls in the Mumbai offshore of

Maharashtra. Mumbai offshore experiences tropical monsoon climate with an average rainfall of

approximately 14 inches. The temperature ranges from 2ºC in the winter to 45 ºC in the summer. The

following are the well-defined seasons of the region:

Summer: February to June

Monsoon: July to September

Winter: October to January

The average rainfall during the last 10 years has been more than 300 mm. The general weather

conditions are not good for agriculture harvest.

Average rainfall

Average rainfall of the proposed exploratory block is in the range of 1mm to 2 mm /day as per ‘Physical

Sciences Division, Earth System Research Laboratory, NOAA, Boulder, Colorado, from their Web site at

http://www.esrl.noaa.gov/psd/’.

Maximum value of average rainfall in the region is 8.3 mm/day and minimum value is 0.045 mm/day.

Figure 3.14 given below reciprocates the mean rainfall of the area in mm/day.


24

FIG. 3.11: WIND PATTERN OF INDIAN OCEAN

Mean Wind Speed

As per Physical Sciences Division, Earth System Research Laboratory, NOAA, Boulder, Colorado, from

their Web site at http://www.esrl.noaa.gov/psd/, mean wind speed measured in m/sec for the period of

January 2011 to December 2011 for the study area lies in the range of 6.1 to 6.8 m/sec. Minimum and

maximum value of the same in the region is 3.5 m/sec and 9.98 m/sec. Figure 3.13 given below shows

the mean wind speed (m/s) of the Arabian sea.


25

FIG. 3.12: MEAN RAINFALL (MM/DAY)

FIG. 3.13: MEAN WIND SPEED (M/S)


26

“V” component of Wind

"V" component represents the north-south component. The positive V component answer indicates a

southerly component to the wind, or in other words, a wind that blows from south to north. A negative V

component would mean that the wind is blowing from north to south. Mean value of V component of wind

in the region of proposed exploratory block lies in the range of -1m/s to 0 m/s as per ‘Physical Sciences

Division, Earth System Research Laboratory, NOAA, Boulder, Colorado, (http://www.esrl.noaa.gov/psd/).

Figure 3.14 below shows the V component of wind speed (m/s) showing the tentative location of block.

Fig.3.14: Mean V component of the wind

“U” Component of Wind

The "U" component represents the east-west component of the wind. The minus sign in front of the U

component answer indicates an easterly component to the wind, or in other words, a wind that blows

from east to west. A positive U component would mean that the wind is blowing from west to east.

According to Physical Sciences Division, Earth System Research Laboratory, NOAA, Boulder, Colorado

(http://www.esrl.noaa.gov/psd/), mean value of u component of wind, averaged over January 2011 to

December 2011 in the region of proposed exploratory block lies in the range of 2 m/s to 3.5 m/s. Figure

3.15 given below shows the U component of wind speed (m/s) of the Arabian Sea indicating the tentative

location of block.


27

Mean Air Temperature

Maximum and minimum value of mean air temperature in the Arabian Sea is of the order of 30.2 ºC and

24.4 ºC, respectively. Mean air temperature of the area of exploratory block lies in the range of 26.5 ºC

to 27.5 ºC as per data available with Physical Sciences Division, Earth System Research Laboratory,

NOAA, Boulder, Colorado. Figure 3.15 given below indicates the mean air temperature of the Arabian

Sea showing tentative location of block.

FIG. 3.15: U COMPONENT OF WIND (M/S)

Mean Sea Surface Temperature

Maximum and minimum value of mean sea surface temperature in the Arabian Sea is of the order of 30.8

ºC and 26.04 ºC, respectively. Mean air temperature of the area of exploratory block lies in the range of

27 ºC to 27.5 ºC as per data available with Physical Sciences Division, Earth System Research

Laboratory, NOAA, Boulder, Colorado.

Tides

The tides in the offshore area are of mixed semi-diurnal type with a large diurnal inequality. The tidal

range in the gulf is about 4 m at the mouth and increase to around 7 m in the inner gulf. This macro-tidal

range is associated with strong water flows during ebb and flood tides. The gulf waters 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; however the impacts of the complex


28

physiographic features on the shelf circulation and shelf sediment dynamics remain unexplained. This

behaviour of the gulf is in sharp contrast to the estuaries on the west coast of the India, which show

seasonal stratification, sometimes with salt –wedge formation associated with the height of the two

monsoons. Figure given in Fig 3-11 indicates the mean sea surface temperature of the Arabian Sea

showing tentative location of block.

FIG. 3.16: MEAN AIR TEMPERATURE (ºC)

FIG. 3.17: MEAN SEA SURFACE TEMPERATURE (ºC)


29

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.


30

Chapter- 4

DESCRIPTION OF ENVIRONMENT

This chapter describes the existing environmental settings in the block MB-OSN-2005/3 and

its immediate surroundings comprising of physical environment, namely, air, water and land components,

the biological environment. Attributes of the physical environment were assessed primarily through

collection and analyses of surface water samples by IPSHEM, ONGC Goa. Records and literature

available in public domain were studied for amassing information about physical and ecological features

of marine environment.

4.1. STUDY AREA

The NELP VII Block MB-OSN-2005/3 is located in the southwest of the Mumbai High-DCS

platform of Mumbai Offshore Basin, having an area of 1685 km2 having 90-100 meter bathymetry range.

The distance between block boundary and the coastal area is about 138 NM.

4.2. STUDY COMPONENTS:

Components for the EIA study of the proposed exploratory block include Climate &

Meteorology, Physico-chemical parameters of sea surface water and ecologically sensitive marine areas.

The details of the study parameter, its study area and study components are given in Table 4.1.

TABLE 4.1: DETAILS OF STUDY COMPONENTS, STUDY AREA AND STUDY PARAMETER

Sr. No. Study Components Study Area Study Parameters

1. Climate & Meteorology MB-OSN-2005/3 and Mumbai high offshore

Wind pattern, ocean currents, rainfall, wave height and direction.

2. Physico-Chemical characteristics of marine surface water

MB-OSN-2005/3 block area within 1 km2 from the proposed drilling locations.

Physical parameters – pH, Salinity, temperature. Chemical Parameters – Oil & Grease, Total Petroleum Hydrocarbon (TPH), Petroleum aromatic Hydrocarbon (PAH)

3 Ecology MB-OSN-2005/3 and Mumbai high offshore

Marine ecology for the Mumbai Offshore and coastal areas near the block.

4 Marine Sensitive Areas No sensitive areas fall within 1 km from the project activity area.


31

4.3. BASELINE ENVIRONMENT

Introduction

Oil and Natural Gas Corporation Limited (ONGC) started oil exploration activities in western

offshore region in the early 70's. After the discovery of oil at Bombay High in 1974, from the first offshore

rig - Sagar Samrat, ONGC increased its attention towards Bombay High. True to expectations, ONGC

has delineated several major and minor oil fields on the western continental shelf.

During the various phases of development of Oil and Gas fields in western offshore, ONGC

has deployed several drilling rigs and commissioned process complexes besides more than a hundred

unmanned platforms. Strict controls by the Government necessitated ONGC to device plans to minimize

impacts from the offshore activities on the environment.

Though ONGC developed its own self control strategies in the initial phases of oil field

development by following international norms and practices, enactment of environment legislation and

regulation by the Ministry of Environment & Forests (MoEF) culminated in closer scrutiny of operations

by both governmental and non-governmental agencies. The Government also imposed several

conditions viz. incorporating preventive measures in the design, emergency preparedness for accidental

pollution and regular environment monitoring around the installations.

The first such environment monitoring was carried out by IPSHEM, Goa as a two season

study (post monsoon season and pre monsoon season) during November 1994 and March 1995. As the

variation of result is not significant, it was decided to carry out once in a year and since the year 2003,

the offshore environment monitoring around the ONGC’s installations in the western offshore region is

being conducted every year regularly.

4.3.1 Objectives and Scope of the Study

As mentioned above, ONGC as per the directives of the Government has started regular

environment monitoring around its installations in the western offshore region, to identify if there are any

impacts on the marine life due to its oil field activities. The objectives of the study are;

To generate a data bank of various important parameters by monitoring the water column

near the offshore installations and beyond 6 km from the installations, can be considered as

reference points.

To assess the spatial and temporal effects on marine benthic communities by sea bed

monitoring.

4.3.2 Scope of work

Collection of water samples in water column for monitoring hydrographical chemical and

biological characteristics including pollutants like hydrocarbons and heavy metals.


32

Collection of sediment samples for quantifying hydrocarbon deposition, heavy metal

concentrations and benthic biota.

Collection of a few samples of zooplankton and fish in the vicinity of oil fields to understand

and estimate the possible bioaccumulation of pollutants.

The monitoring strategy including the fixing of sampling stations was guided by the Paris

Commission Guidelines (1987) and practices adopted in Gulf of Mexico (EPA - 1985). The

ocean monitoring methods adopted in India (Anon, 1994) were also taken into account while

designing the monitoring programme.

The Paris convention seeks to prevent pollution of the marine environment by virtually all

substances that can reach sea. All types of human activities are regulated within the

framework of this convention. The convention, in its meeting during June 1988 adopted the

guidelines framed by the Norwegian Pollution Control Authority for standardizing the

monitoring programme of offshore oil and gas platforms. These guidelines are called Paris

Commission (PARCOM) guidelines.

In general, the parameters to be studied and the frequency of monitoring are decided by the

local authorities. These guidelines are useful in fixing of sampling stations around the

platforms. The guidelines are based on the overall objective of environmental monitoring,

namely to assess the effects and extent of the spreading of oil and chemicals discharged

from the offshore industry into the marine environment.

4.3.3 Methodology

The task of offshore environment monitoring is needed the coordination of various agencies like,

A survey vessel to go around the offshore area for sample collection, analysis on board and

preservation of some samples;

A biological team for collection and interpretation of marine biological samples;

Fixing of sampling stations around offshore installation — these were governed by the Paris

commission guidelines as detailed above.

The survey vessel would cruise to the locations where samples were desired as per the given

geographical coordinates (lat/long) were collected and preserved for analysis. The typical sample

collection sketch conforming to international standards is shown in Fig. 4.1.

In view of this, IPSHEM adopted the following methods to execute the project.


33

Fig. 4.1: Typical lay out of sampling stations based on Paris Commission Guidelines

4.3.4 Association of Biological Expertise:

Agency, having well experienced in Offshore Environment Monitoring and engaged in all

types of Oceanographic studies like Physical, Chemical, Biological and Geological studies

was approached for this study. A senior scientist working in the Biological division of the

agency was associated for the biological part of the study. He has carried out similar

biological work in the past in the coastal and offshore marine environment.

Cruise Vessel

A research vessel scrutinized by ONGC offshore security and offshore Defense Advisory

Group was hired by the agency. It should have bow and stern thrusters, auto steering

system, radio communication and satellite telephone etc. in addition to GPS and Radar for

accurate positioning of the vessel. It will be equipped with computerized weather monitoring

system and a well-set laboratory for analysis and preservation of samples. The cruise route

and the sample locations along the cruise route is depicted in the Fig. 4.2.


34

4.3.5 Description of study area and Sampling locations:

The sampling stations around these installations were fixed based on Paris Commission

Guidelines, 1989 and was also guided by the following criteria.

Pipeline network in the immediate vicinity of the platform

Sea state and maneuverability of the vessel near the installation

In this study, two locations viz. Location-1 and Location-2 were covered to know the environmental status

of specific portion of Western Offshore. The sampling locations around all these locations are given

below.

Fig. 4.2: Cruise Sailing Route


35

Coordinates of the Sampling stations

Approach

towards

Installation/

Direction

Distance from

the location

Sample

number Location Code Latitude Longitude

North- 1

2 km RA4-1 RA4/2/1 19007’26” 70056’24”

1 km RA4-2 RA4/1/1 19006’53” 70056’39”

0.5 km RA4-3 RA4/0.5/1 19006’32” 70056’37”

South West -2

2 km RA4-4 RA4/2/2 19005’38” 70055’26”

1 km RA4-5 RA4/1/2 19005’48” 70056’13”

0.5 km RA4-6 RA4/0.5/2 19006’04” 70056’26”

South East-3

2 km RA4-7 RA4/2/3 19005’29” 70057’27”

1 km RA4-8 RA4/1/3 19005’44” 70056’48”

0.5 km RA4-9 RA4/0.5/3 19005’58” 70056’48”

Reference Point >6 Km RA4-10 RA4/6/1 19002’38 70057’15”

Coordinates of the Sampling stations

Installation Latitude Longitude

Location -2 19014’26” 70058’52”

Approach

towards

Installation/

Direction

Distance from

the location

Sample

number Location Code Latitude Longitude

North- 1

2 km RGD-1 RGD/2/1 19015’28” 70058’47”

1 km RGD-2 RGD/1/1 19015’01” 70058’47”

0.5 km RGD-3 RGD/0.5/1 19014’44” 70058’57”

South West -2

2 km RGD-4 RGD/2/2 19013’35” 70058’20”

1 km RGD-5 RGD/1/2 19013’54” 70058’32”

0.5 km RGD-6 RGD/0.5/2 19014’14” 70058’37”

South East-3

2 km RGD-7 RGD/2/3 19013’37” 70059’46”

1 km RGD-8 RGD/1/3 19013’52” 70059’17”

Installation Latitude Longitude

Location-1 19006’05” 70056’26”


36

0.5 km RGD-9 RGD/0.5/3 19014’09” 70059’08”

Reference Point >6 KM RGD-10 RGD/6/1 19010’52” 70059’05”

4.3.6 Equipment used for Sampling:

Mechanical Instruments

Electro-hydraulic winch

Hydrographic winch

Van Veen Grab

Single arm davits

Nishkin Bottle Sampler

Plankton nets

Electronic Instrument

Echo Sounder

CTD

DGPS

AWS

UPS

pH meter

Spectrophotometer

Spectroflouro meter

Computer

Sampling of water

All Seawater samples were collected from three levels of the water column-surface (1 m below

the surface), mid depth and near bottom (3 - 4 m above the sea bed) using PVC Niskin type samplers of

5 L capacity. Depth measurements were made to the nearest 1 m using a digital counter attached to the

pulley and counter checked by marking the cable.

Sampling of sediments

A Van Veen grab of 25 cm x 30 cm dimension and approximately 1.5 kg capacity having a

penetration depth of 10 cm was used for collection of sediments. This medium version of the grab was

used to prevent likely damage to pipelines etc. in case of any accidental strike on flow lines.

Sampling of plankton and benthos

Zooplankton samples were collected with a modified Heron-Tranter (HT) net; having 0.25m2

mouth areas and 330m mesh size. A horizontal haul of similar plankton net of 60 mesh size was used

for collection of mixed plankton. The collections were made during the period sunrise to sunset only.

Storage and Preservation

Samples of sea water (1 L) were preserved in polythene bottle after addition of metal free

hydrochloric acid for further analysis of heavy metals in the laboratory. Two aliquots of 1 L, each were

filtered through GF/F filters (pore size 0.70pm) and extracted with 10mL of 90% acetone under cold dark

conditions after an extraction period of 18 to 20 hours. The extract (g.L -1) was determined using

fluorometer. Column chlorophyll-a (mg m-2) was calculated by integrating the depth values.


37

Zooplankton samples were preserved in 5% neutral formalin for further identification and

quantification. Sediment samples were made to stand in 5% buffered Rose- Bengal formalin for 24 hours

and then sieved onboard the vessel using standard sieves for collection of benthic organisms. The fauna

thus collected were stored in 4% neutral formalin for subsequent analysis. Samples for sediments were

also collected in aluminum foil and preserved at -20° C for hydrocarbon analysis. Another set of sediment

samples were collected in pre washed polythene bags and preserved at room temperature for grain size

analysis and the determination of heavy metals. Samples of fish and fish tissues were collected onboard

in aluminum foils and polythene bags and stored at -20° C for subsequent determination of hydrocarbons

and heavy metals in the laboratory.

Analytical Methods

Immediately after collection, seawater samples were analyzed for pH and nutrients (Nitrate,

Nitrite, Phosphate and Silicate). Nutrients were analyzed using chemical methods (Grasshoff, 1987).

Petroleum Hydrocarbons were extracted immediately after collection of seawater onboard the vessel

from 500 ml of seawater with spectroscopic grade n-hexane and the extract was preserved at 5°C for

further analysis in the laboratory.

Parameters like temperature, salinity, dissolved oxygen were determined, onboard the vessel,

using the CTD profiler and the values were double-checked using manual methods.

At each of the station, zooplankton was collected, by deploying a Heron-Tranter net fitted with

calibrated TSK flow meter at the mouth area. The net was towed horizontally at a uniform speed of 1.5

knots for five minutes. After initial processing onboard the ship, zooplankton samples were further studied

for population density, biomass, faunal composition and taxon diversity by using standard procedures.

Sea bottom dwelling organisms or benthos were collected, at each of the station, by lowering

a Van Veen Grab having penetration depth of 10 cm and variable surface coverage of 587.5 cm2 (small

grab) and 1035 cm2 (large grab). Meiobenthos sampling was done by using a plexiglass core of 4.5 cm

diameter. Macrobenthos samples were processed onboard the vessel, by sieving through 500 micron

stainless steel mesh screen for 48 hours whereas the samples for meiobenthos were passed through a

63 micron sieve. Organisms - meio and macro were treated with Rose Bengal stain and further preserved,

in 5% seawater formalin.

Bottom deposits were classified into dominant sediment type by visual touch-on method. Silty

- clay followed by sand were the dominant sediment types.

The methods followed for analyzing various parameters have been taken from standard books

on the subject of seawater analysis and conform to US EPA standards.

Winds


38

The meteorology of the study area is governed by the monsoon system inducing alternating

winds and currents. The Northeast monsoon winds (November-February) are rather moderate, compared

to the Southwest monsoon winds (June to September). The meteorological data recorded in the vicinity

of these two stations are given in table No: 1.

Sediment characteristics

The continental shelf of western offshore region is approximately 140 nautical miles of the

coast of Mumbai. The shelf is distinguished as an inner and outer part, the demarcation being the 60 m

isobaths (Nair & Hashmi, 1980). The inner shelf is dominated by recent terrigenous deposits while the

outer shelf is characterized by relict oolite sand (Satyaprakash and Agarwal, 1981). The sedimentary

cover of the continental shelf exhibits a seaward succession of increasing granulometry from clay to silt

and sand (Nair and Hashmi, 1980)

The sediment samples collected at various locations during the present study also revealed

that the sediments were not uniformly distributed in the study area.

4.3.7 Methodology Followed for the analysis of Hydrographical and Chemical Parameters

4.3.7.1 Hydrographical Parameters

Temperature

Temperature was measured using the centigrade thermometer with a graduation of 0 - 100

°C. This is an important parameter since the characteristics of water column like the density, viscosity,

solubility, of gases and dissolved oxygen are related to temperature of the water column. The variation

in temperature of a water body has great impact upon the biological productivity. The organism including

fishes show limited tolerance for variation in temperature for processes such as feeding, reproduction

and movement. Distribution of aquatic organism is greatly influenced by water temperature.

During the survey it was revealed that the water column experienced homogeneous and

uniform distribution of temperature indicating that the impact of the offshore operation on the thermal

regime of the water column is insignificant.

pH

pH was measured using a portable pH meter ( Systronics) with an accuracy of ± 0.01 pH units.

pH meter was first calibrated with standard pH buffers of pH 7.0 and pH 4.0.

Salinity

Salinity was measured directly by Systronics water analyzer with an accuracy of 0.1ppt. Prior to the

sample, standard seawater was used to calibrate the salinometer.


39

Turbidity

Turbidity was measured by Nephelometric method and the results are expressed in

Nephelometric Turbidity units (NTU). This method was based on a comparison of an intensity of light

scattered by the sample under defined conditions with the intensity of light scattered by a standard

reference suspension under the same conditions. The greater the intensity of the scattered light, the

higher is the turbidity. Standard turbidity suspensions for calibration were prepared by using hydrazine

sulphate and hexamethylene tetramine and the analysis were carried out using turbidity meter.

Suspended Solids

A known volume of seawater was filtered through a pre-weighed 0.45m Millipore filter paper.

This paper was dried till constant weight was obtained. The difference in initial weight and the weight

after filtration and drying was taken and the amount of suspended solids calculated.

4.3.7.2 Chemical Parameters

Dissolved Oxygen

Dissolved Oxygen (DO) was measured directly by Systronics water analyzer with an accuracy of

0.1ppm. The values of DO are expressed in mg/L.

Nutrients

Phosphate — Phosphorus

Dissolved reactive phosphate was measured by the method of Murphy & Riley in which the

seawater samples were made to react with acidified molybdate reagent and reduced using ascorbic acid.

The absorbance of the resultant blue complex was measured at 880 nm using HACH (DR- 3900)

spectrophotometer.

Nitrite — Nitrogen

Nitrite was measured by the method of Bendschneider and Robinson wherein the nitrite in

the samples was determined by diazotising with sulfanilamide and coupling with N (1-Naphthy)-ethylene

diamine-dihydrochloride. The absorbance of the resultant azo-dye was measured at 543 nm by a HACH

(DR- 3900) spectro-photometer.

Nitrate — Nitrogen


40

Nitrate in the samples was first reduced quantitatively to nitrite by heterogeneous reduction

by passing the buffered seawater samples through an amalgamated cadmium column and the resultant

nitrite was analyzed as above. The measured absorbance was due to the initial nitrite in the sample and

nitrite obtained after the reduction of nitrate. Necessary correction was therefore made for any nitrite

initially present in the sample.

Silicates

The determination of silicates in seawater was based on the formation of a yellow

silicomolybdic acid when a nearly acidic sample was treated with a molybdate reagent. The yellow

silicomolybdic acid was reduced to an intensely colored blue complex using ascorbic acid as the

reductant and the colour was measured spectrophoto metrically.

Petroleum Hydrocarbons

Dissolved / dispersed petroleum hydrocarbons were extracted from seawater with Methylene

Chloride followed by GC- FID Analysis using Thermo (GC- 1000) GCFID.

Sediment

Total Phosphorus

The organic phosphorus was converted into inorganic form by digestion of sediment with

perchloricacid and the phosphorous was estimated using standard methods applicable for the

estimation of inorganic phosphate phosphorus by spectrophotometric method.

Total Nitrogen

Total nitrogen was estimated by the persulphate oxidation technique in which the nitrogen

compounds were converted to nitrates by alkaline persulphate at 115 °C (in an autoclave under

pressure) and the resultant NO3 was reduced to NO2 by passing through the cadmium amalgamated

column. Finally the NO2 was estimated by diazotization and coupling with aromatic amines and

measured at 543 nm by a spectrophotometer.

Total Organic Carbon

Total carbon present in organic material in sea sediment is estimated with the help of muffle furnace

using semi- quantitative method and finally total organic carbon is calculated in percentage.

Petroleum Hydrocarbons


41

Dried sediment sample was digested with the perchloricacid and PHC was measured with Thermo (GC-

1000) GC-FID.

4.3.8 RESULTS AND DISCUSSION

Drilling Rig-Abban Ice and Drilling Rig-GD Chayya are retitled as Station-1 and Station-2

respectively during the following discussion to avoid complexity. The data of chemical characteristics,

dissolved oxygen, nutrients like nitrate, nitrite, phosphate and silicate as recorded around these stations

of Western offshore are presented in following Tables.

4.3.8.1 Temperature

Sampling Points around the station-1 and Station-2 have shown temperature’s variation from

26.2-28.3 °C and 26.2-28.3 °C respectively and an average temperatures were detected of 27.31 °C and

27.11 °C respectively. The surface layer showed higher temperature at all the stations, which decreased

towards the bottom. At station-1 reference point, temperature was varying from 26-26.9 °C whereas at

station-2 reference point, temperature was 26.1-26.8 °C. The observed range of temperature variation is

well in normal limits for the coastal waters.

4.3.8.2 pH

Sampling Points around the station-1 and Station-2 have shown pH’s variation from 7.12-8.3

and 6.75-8.25 respectively and an average pH values were detected of 7.78 and 7.67 respectively. At

station-1 reference point, pH was varying from 7.21-8.28 whereas at station-2 reference point,

temperature was 7.1-8.26. No particular trend is followed regarding the distribution of pH, though all the

observed pH values are well within normal limits.

4.3.8.3 Salinity

Sampling Points around the station-1 and Station-2 have shown salinity’s variation from 31.5-

37.5 PSU and 31.6-38.4 PSU respectively and an average salinity values were detected of 34.4 PSU and

35.57 PSU respectively. At station-1 reference point, salinity was varying from 33.8-36.8 PSU whereas

at station-2 reference point, salinity was 36.7-37.5 PSU. The observed salinity values are similar to those

observed at the reference stations and the values are well within acceptable limits.

4.3.8.4 Turbidity

Sampling Points around the station-1 and Station-2 have shown turbidity’s variation from 4.6

– 16.8 NTU and 3.4 – 17.4 NTU respectively and an average turbidity values were detected of 10.31 NTU

and 9.02 NTU respectively. At station-1 reference point, turbidity was varying from 8.4-10.9 NTU whereas

at station-2 reference point, turbidity was 4.6-9.6NTU. The variation of turbidity has followed no trend and

the observed turbidity indicate normal values for the seawater at the site.


42

4.3.8.5 Total Suspended Solids

Sampling Points around the station-1 and Station-2 have shown the Total Suspended Solids

(TSS)’s variation from 10-38 mg/L and 9-34 mg/L respectively and an average TSS values were detected

of 24.98 mg/L and 18.63 mg/L respectively. At station-1 reference point, TSS was varying from 20-41

mg/L whereas at station-2 reference point, TSS was 13-16 mg/L. The vertical variation of suspended

solids shows no characteristic trend, however comparing the values with reference point; disturbance of

operational activity cannot be concluded. The observed values are within normal limits for the coastal

seawater

4.3.8.6 Dissolved Oxygen DO

Dissolved Oxygen (DO) concentrations are considered to be very vital parameter to assess

the health of the marine environment especially where exploration and production activities are in

progress. The measured DO concentrations around station-1 and station-2 have almost shown

predictable a variation depends on depth at which sample was collected (In general, DO concentrations

are decreased when depth is increased).

Sampling Points around the station-1 and Station-2 have shown the DO’s variation from 3.24-

5.38 mg/L and 3.25-5.34 mg/L respectively and an average DO values were detected of 4.42 mg/L and

4.30 mg/L respectively. At station-1 reference point, DO was varying from 3.52-5.38 mg/L whereas at

station-2 reference point, DO was 3.67-4.67mg/L. Subsequently, studying all these experimental results

carefully, it is observed that all obtained values are most similar to the values obtained at reference station

values and well within acceptable limits for the coastal seawater.

Nutrients

i. Phosphate - Phosphorous

Sampling Points around the station-1 and Station-2 have shown Phosphate– Phosphorus

(PP)’s variation from 0.042–0.84 μmol/L and 0.045–0.75 μmol/L respectively and an average PP values

were detected of 0.21 μmol/L and 0.21 μmol/L respectively. At station-1 reference point, PP was varying

from 0.10-0.19 μmol/L whereas at station-2 reference point, PP was 0.16-0.19 μmol/L. The vertical

variation of phosphates at these stations showed no regular trend of phosphate phosphorous. The values

observed however are normal for the coastal seawater.

ii. Nitrite – Nitrogen

Sampling Points around the station-1 and Station-2 have shown Nitrite – Nitrogen (NN)’s

variation from 0.008 – 0.026 μmol/L and 0.007 – 0.027 μmol/L respectively and an average NN values

were detected of 0.016 μmol/L and 0.015 μmol/L respectively. At station-1 reference point, NN was

varying from 0.013-0.017 μmol/L whereas at station-2 reference point, NN was 0.015-0.016 μmol/L. The


43

Nitrite – Nitrogen values follows no particular trends and they are similar at all the stations and at all the

water columns. The values observed as well within normal acceptable limits

iii. Nitrate - Nitrogen

Sampling Points around the station-1 and Station-2 have shown Nitrate – Nitrogen (NN)’s

variation from 0.015 – 4.5 μmol/L and 0.022 – 0.67 μmol/L respectively and an average NN values were

detected of 0.85 μmol/L and 0.30 μmol/L respectively. At station-1 reference point, NN was varying from

0.014-0.34 μmol/L whereas at station-2 reference point, NN was 0.037-0.043 μmol/L. The Nitrate –

Nitrogen values follows no particular trends and values are at lower side. The values are within normal

acceptable limits.

iv. Silicates

Sampling Points around the station-1 and Station-2 have shown Silicate’s variation from 0.12-

0.57 μmol/L and 0.16-0.45 μmol/L respectively and an average Silicate values were detected of

0.31μmol/L and 0.29 μmol/L respectively. At station-1 reference point, Silicate was varying from 0.28-

0.51 μmol/L whereas at station-2 reference point, Silicate was 0.29-0.35 μmol/L. The observed values

are normal for the coastal seawater.

v. Petroleum Hydrocarbons (PHC)

Sampling Points around the station-1 and Station-2 have shown (Table-4.1) PHC’s

concentration very minimal at majority of points which comes under non detection limit. At both the

reference stations also, the PHC comes under non detection level.

The distribution of PHC in the sediment samples at and around the both stations has shown

(Table.7) minute contamination, though all observed valued values are acceptable limits.

Sediment Quality

Total Phosphorous and Total Nitrogen

The Total Phosphorous and Total Nitrogen’s concentration was measured in the sediment

samples collected around the sampling points of station-1 and Station-2 has shown variation from 19.7—

40.2 μg/g and 8.6—30.1 μg/g respectively and an average values were detected of 29.2 μg/g and 25.2

μg/g respectively. At station-1 reference point, the concentration was 92.4 μg/g whereas at station-2

reference point, it was 64.2 μg/g.

Total organic carbon

The Total Organic Carbon’s concentration was measured in the sediment samples collected

around the sampling points of station-1 and Station-2 has shown variation from 1.9% to 4.7% and 2.0%


44

to 4.2% respectively and an average values were detected of 3.0% and 3.0%μg/g respectively. At station-

1 reference point, the concentration was 3.1% whereas at station-2 reference point, it was 1.4%.

PHC content in Sediment

The PHC’s concentration was measured in the sediment samples collected around the

sampling points of station-1 and Station-2 has shown variation from 45.62– 86.74 g/g and 42.81– 89.67

g/g respectively and an average values were detected of 64.055 g/g and 69.42 g/g respectively. At

station-1 reference point, the concentration was 34.51g/g whereas at station-2 reference point, it was

46.52g/g. Though all the stations are contaminated with PHC’s, the values are within acceptable limits.

Sediment textures

The texture of sediment samples collected around the station-1 and station-2 has been

analyzed systematically and it has been observed that the composition of clay varies from 30% -42% and

57% -80% respectively with average value of 36.71% and 69.7% respectively. At station-1 reference

point, it was 31% whereas at station-2 reference point, it was 36%.

Table - 4.1:: Meteorological parameters

Sr. No. Parameter Unit Location: 1

Date : 26.10.13

Time : 07:30 am

Location: 2

Date : 26.10.13

Time : 01:45 pm

1 Latitude - 19° 05’ 69” N 19° 13’ 157” N

2 Longitude - 70° 57’ 46” E 70° 57’ 714” E

3 Speed Knots 1.2 1.3

4 Heading ° C 220 15

5 Coarse ° C 214 10

6 Depth m 84 79

7 Wind Crest m/sec 2.7 3.4

8 Wind Speed m/sec 7.72 8.75

9 Wind Direction - NE NE

10 Air Temp. °C 30 29

11 Pressure mbar 1009.3 1010.7

Table-4.2 :: Hydrographical Parameters of Sea Water Column around Offshore Stations

Location: 1

Station Distance from Station Depth Temp Salinity pH Turbidity Suspended solids

°C PSU pH Unit NTU mg/l

1 0.5 km S 28.3 33.4 7.94 5.9 24


45

M 27.7 32.5 7.21 4.6 20

B 27.5 31.5 7.51 7.6 36

2 1 km

S 27.8 35.9 7.68 11.2 19

M 27.5 34.8 8.14 10.6 17

B 27 33.4 7.14 12.7 15

3 2 km

S 27.6 35.6 7.65 5.4 25

M 27.2 33.2 7.58 8.3 27

B 26.9 31.6 8.16 15.4 16

4 0.5 km

S 27.4 33.8 8.14 12.6 23

M 27.1 35.6 8.16 14.3 10

B 26.9 33.9 7.95 12.5 18

5 1 km

S 27.5 34.5 8.16 11.6 29

M 26.7 36.8 8.13 13.8 37

B 26.2 37.5 7.79 11.4 28

6 2 km

S 27.9 34.6 7.54 12.6 36

M 27.4 36.8 8.15 5.6 38

B 27 34.2 7.68 8 21

7 0.5km

S 27.5 32.1 7.45 14.7 16

M 27.8 36.7 8.3 6.8 18

B 26.9 34.7 7.54 5.6 28

8 1 km

S 27.4 31.7 7.68 8.4 26

M 27.6 36.8 7.84 11.2 19

B 27.1 32.9 7.31 13.5 34

9 2 km

S 27.6 34.7 8.19 16.8 25

M 27.2 32.8 8.02 9.8 31

B 26.7 36.8 7.12 7.5 37

R R

S 26.9 33.8 8.28 8.4 20

M 26.4 35.7 8.09 10.9 21

B 26 36.8 7.21 9.6 41

Location: 2

Station Distance from Station Depth Temp Salinity pH Turbidity Suspended solids

°C PSU pH Unit NTU mg/l

1 0.5 km

S 27.9 34.2 6.75 14.3 16

M 27.4 31.7 7.42 3.6 10

B 26.7 36.1 7.21 4.6 19


46

2 1 km

S 27.3 34.8 7.52 12.7 24

M 26.8 35.9 7.31 4.8 27

B 26.2 37.4 8.24 6.9 14

3 2 km

S 27.5 36.7 7.98 4.7 18

M 27 37.8 7.42 6.4 16

B 26.8 35.9 7.86 8.2 14

4 0.5 km

S 27.3 34.2 7.81 12.3 24

M 26.8 36.7 7.58 10.2 29

B 26.5 32.7 7.68 9.5 27

5 1 km

S 27.8 31.6 7.24 5.6 16

M 27.2 32.7 8.25 4.6 16

B 26.7 33.7 8.12 3.4 16

6 2 km

S 27.2 37.6 8.2 4.7 15

M 26.7 36.9 7.86 5.8 21

B 26.3 34.8 7.25 4.5 12

7 0.5km

S 28.3 35.9 7.61 6.7 24

M 27.5 37.4 7.82 13.8 10

B 26.7 35.9 7.95 15.6 14

8 1 km

S 27.9 36.8 8.13 17.4 16

M 27.3 37.1 7.43 13.8 28

B 26.8 36.4 8.1 14.8 34

9 2 km

S 27.7 38.4 7.51 12.9 24

M 27.2 36.4 7.62 11.8 10

B 26.7 34.8 7.41 10.2 9

R R

S 26.8 36.7 7.1 9.6 13

M 26.4 37.5 8.26 4.6 14

B 26.1 36.9 8.2 7.6 16

S-Surface, M-Middle, B- Bottom, R-Reference

Table-4.3 :: Chemical Parameters of Sea Water Column around Offshore Stations

Location: 1

Statio

n

Distance from

Station

Dept

h

Dissolved

oxygen

Nutrients

Nitrite-

N

Nitrate-

N

Phosphate-

P

Silicate-

Si

mg/l mg/l mg/l mg/l mg/l

1 0.5 km

S 5.32 0.019 0.22 0.042 0.43

M 4.6 0.014 2.51 0.12 0.45

B 3.5 0.013 0.39 0.19 0.23

2 1 km S 5.24 0.018 0.21 0.12 0.25


47

` M 4.65 0.018 3.45 0.084 0.26

B 3.24 0.009 0.21 0.14 0.28

3 2 km

S 5.31 0.012 0.29 0.21 0.19

M 4.38 0.021 4.51 0.24 0.24

B 3.65 0.014 0.25 0.23 0.37

4 0.5 km

S 5.31 0.019 0.87 0.21 0.42

M 4.7 0.013 2.6 0.074 0.2

B 3.8 0.014 0.18 0.14 0.26

5 1 km

S 5.37 0.02 0.24 0.19 0.27

M 4.57 0.025 2.63 0.84 0.19

B 3.68 0.017 0.54 0.21 0.32

6 2 km

S 5.1 0.008 0.19 0.16 0.25

M 4.63 0.01 0.015 0.17 0.16

B 3.57 0.011 0.16 0.18 0.36

7 0.5km

S 4.75 0.015 0.28 0.25 0.31

M 3.85 0.021 1.3 0.24 0.36

B 3.52 0.02 0.28 0.29 0.45

8 1 km

S 4.75 0.008 0.54 0.27 0.29

M 4.67 0.026 0.015 0.26 0.23

B 3.57 0.013 0.19 0.095 0.32

9 2 km

S 5.26 0.022 0.42 0.27 0.31

M 4.6 0.024 0.017 0.16 0.26

B 3.68 0.012 0.53 0.18 0.27

R R

S 5.38 0.016 0.32 0.19 0.34

M 4.6 0.013 0.014 0.16 0.35

B 3.52 0.017 0.34 0.1 0.29


Location: 2

Statio

n

Distance from

Station

Dept

h

Dissolved

oxygen

Nutrients

Nitrite-

N

Nitrate-

N

Phosphate-

P

Silicate-

Si

mg/l mg/l mg/l mg/l mg/l

1 0.5 km

S 5.26 0.019 0.46 0.23 0.26

M 4.87 0.023 0.61 0.16 0.42

B 3.97 0.027 0.31 0.17 0.16


48

2 1 km

S 4.36 0.016 0.2 0.24 0.34

M 4.24 0.019 0.29 0.36 0.12

B 3.56 0.012 0.34 0.26 0.21

3 2 km

S 4.85 0.018 0.38 0.75 0.18

M 4.25 0.013 0.25 0.16 0.31

B 3.52 0.014 0.29 0.23 0.51

4 0.5 km

S 5.34 0.021 0.34 0.16 0.42

M 4.37 0.014 0.36 0.075 0.31

B 3.67 0.007 0.38 0.19 0.42

5 1 km

S 5.21 0.009 0.21 0.52 0.21

M 4.37 0.012 0.27 0.21 0.35

B 3.59 0.015 0.25 0.16 0.14

6 2 km

S 4.92 0.017 0.29 0.19 0.26

M 4.25 0.019 0.23 0.089 0.49

B 3.61 0.016 0.25 0.23 0.25

7 0.5 km

S 4.86 0.015 0.21 0.25 0.27

M 4.23 0.012 0.049 0.21 0.34

B 3.64 0.008 0.67 0.075 0.32

8 1 km

S 5.3 0.014 0.41 0.15 0.39

M 4.31 0.007 0.022 0.045 0.34

B 4.13 0.014 0.54 0.19 0.46

9 2 km

S 4.67 0.019 0.24 0.12 0.35

M 3.69 0.024 0.041 0.069 0.33

B 3.25 0.02 0.16 0.095 0.25

R R

S 4.38 0.013 0.38 0.19 0.28

M 4.67 0.16 0.037 0.18 0.39

B 3.67 0.015 0.43 0.16 0.51


Table - 4.4 :: Petroleum Hydrocarbon (mg/L) in water samples

Station Depth 0.5 km 1 km 2 km 0.5 km 1 km 2 km 0.5 km 1 km 2 km R

1 2 3 4 5 6 7 8 9 10

Location-1

S ND ND ND ND ND ND ND ND ND ND

M ND ND ND ND ND ND ND ND 0.24 ND

B ND ND ND ND ND ND ND ND ND ND

Location-2 S ND ND ND ND ND ND ND ND ND ND


49

M ND ND 0.18 ND ND ND ND ND ND ND

B ND ND ND ND ND ND ND ND ND ND

Table - 4.5 :: Total Nitrogen (µg/g), Total Phosphorous (µg/g) and Organic carbon (%) in sediments

ABAN ICE (Loc-1)

Distanc

e

Total

Phosphoru

s

Total

Nitroge

n

Total

Org.

Carbon

GD

Chayya

(Loc-2)

Distance

Total

Phosphoru

s

Total

Nitrogen

Total

Org.

Carbo

n

( Km) µg/g µg/g % ( Km) µg/g µg/g %

1 0.5 27.2 66.4 4.7 1 0.5 20.7 57.8 2.6

2 1 36.1 52.1 2.6 2 1 9.4 67.5 2

3 2 21.3 78.3 3.2 3 2 18.9 86.9 3.4

4 0.5 30.6 88.4 3.6 4 0.5 8.6 43.7 2.1

5 1 40.2 73.5 2 5 1 23.2 76.1 4.2

6 2 19.7 51.8 1.9 6 2 15.8 51.4 3.7

R R 25.2 92.4 3.1 7 0.5 11.2 39.3 2.9

8 R 30.1 64.2 1.4

R-Reference

Table - 4.6 :: Sediment Texture Analysis around Sampling Stations

Location1 Distance

(Km)

Silt Clay Location 2 Distance

( Km)

Silt Clay

% % % %

1 0.5 42 39 1 0.5 27 73

2 1 39 35 2 1 39 60

3 2 36 30 3 2 42 57

4 0.5 40 36 4 0.5 21 79

5 1 49 42 5 1 36 68

6 2 44 38 6 2 26 80

R R 36 30 7 0.5 29 71

8 R 31 62

R-Reference

Table - 4.7:: Petroleum Hydrocarbon (μg/g) in sediment samples

Station 0.5 km 1 km 2 km 0.5 km 01 km 02 km 0.5 km 01 km 02 km R

1 2 3 4 5 6 7 8 9 10

ABBAN 86.74 75.62 45.62 72.34 46.87 57.14 - - - 34.51

CHAAYA 87.68 76.58 86.64 48.67 53.89 42.87 89.67 - - 46.52

Heavy Metal concentrations


50

Various heavy metals are present in small concentrations in the marine environment. Metal

pollution in the seas is invisible and insidious and does not attract enough attention as compared to oil

pollution, unless catastrophic events like the Minamata case of Japan occurs (which was due to Mercury

poisoning). In aquatic environments – metals can be termed as ‘conservative pollutants’, which once

added to the environment are there forever and cannot be broken down to harmless substances by

bacterial action as many of the organic pollutants are. Most of them are however, perfectly natural

substances occurring in seawater, though often in extremely low concentrations. They are leached or

introduced into the aquatic systems as a result of the weathering of soils and rocks, from underwater

volcanic activities, and from a variety of manmade sources, which involve mining, processing or use of

metals or substances that contain metal contaminants. This is which changes the natural concentrations

of metals in seawater resulting in a ten or even a hundred fold increase near the source of an effluent

discharge. Although many metals are poisonous at quite low concentration, they are often vital as trace

elements. Hence, while manganese, copper, iron, zinc etc. are considered essential micronutrients,

mercury, cadmium and lead are not required for any important biological function by any organisms and

are termed as non-essential elements.

Generally speaking, except at a few places, metal pollution in the sea is not and never was at

dangerous levels, but the potential threat it offers is sufficient to merit a careful watch, in terms of

monitoring programs. Metals once introduced in the seawater, either naturally or as contaminants

undergo various alternatives. Apart from dilution and dispersion there are biogeochemical processes

which remove metals from the seawater, or in other words reduce the concentrations of the added metal

in seawater. These are precipitation, adsorption by suspended matter and absorption by organisms. It is

the last process that includes removal by zooplankton ‘debris’ and other organisms which is of prime

concern to man. This has led to much interest in determining the levels of heavy metals in a wide variety

of commercially important marine fishes more as a food hygiene study.

Because of these factors, monitoring the concentrations of heavy metal in water, sediments

and fishes is very important. The toxicity limits (LC50 values) of some heavy metals towards fish in the

open sea are given below:

Table - 4.8 :: Heavy metal and Toxicity Limit

Metal Toxicity Limit (µg/L)

Chromium >10000

Zinc >1000

Cadmium 6400 – 16400

Mercury 67

Lead >1000


51

Since the concentration of heavy metals in seawater is very low (usually in the parts per billion

levels), accurate determination of their concentration is a very delicate and cumbersome task. The

analytical methods using normal flame atomic absorption cannot detect the low concentrations of heavy

metals in seawater (in µg – ng ranges) and do not give reproducible results. Hence all the seawater

samples were analyzed using inductively coupled Plasma emission spectrophotometer (ICP- OES)

available at IPSHEM.

The heavy metal contents in sediments were analyzed after digestion with hydrofluoric acid

and perchloric acid, using same ICP- OES available at IPSHEM. These methods were standardized and

calibrations done using standard metal solutions and standard reference samples. The same equipment

was used for the determination of heavy metals.

Heavy Metals in Seawater

The range of concentration (in µg/L) of heavy metals viz. Zinc, Iron, Cadmium, Lead, Barium,

Manganese, Chromium and Mercury in the sea water sampled at surface, mid depth and bottom of

various sampling stations around Rig.Abban-Ice and Rig.GD Chayy are given in Table 14. Ranges of

some significant heavy metals like Zinc, Iron, Manganese and Lead which are usually present in higher

concentrations (in ppb) than the other heavy metals, and which require close watch from pollution point

of view, have been tabulated.

Table - 4.9 :: Heavy Metal Concentrations at Reference Stations

Heavy Metal Range of Concentration (µg/L) Heavy Metal

Range of Concentration (µg/L)

Ba 1.5-2.2 Mn 0-12.6

Cd 0.2-0.5 Pb 1.25-3.22

Cr 1.6-2.5 Zn 2.7-8.3

Fe 0.23 % - 0.43% Hg 5.8-9.9

The distribution of heavy metals in water column did not reveal any clear pattern either

vertically or horizontally. The spatial distribution also did not yield any clear trend of either enrichment or

depletion.

For some of the heavy metals, the ranges of concentrations (µg/L) in the Indian Ocean have

been reported by various authors is given in Table:4.10.

Table - 4.10 :: Heavy metals concentration in the Indian Ocean

Authors Fe Mn Zn

Sen Gupta et.al. (1978) 7.2 – 66.9 - 0.5 – 42.4


52

Sanzgiri and Moraes (1979) 8.5 – 96 1.8 – 80 1.2 – 29.7

Braganca and Sanzgiri (1980) 6.2 – 131.5 1.8 – 40.8 2.4 - 20

Though the iron contents in seawater recorded in this study are relatively higher in

concentration comparable to the standard values as described above, the concentrations observed in the

reference stations around Bombay High are quite identical to the values recorded near the installations.

This is inferred that there is no enrichment in the heavy metal concentration due to oil field activities in

spite of the fact that the drilling mud discharges and the disposal of produced water are sources of heavy

metals around an oil field installation. Literature review gives an idea of concentration of heavy metals in

various oceans of the world, which is given in Table:4.11

Table - 4.11 :: Concentration (µg/l) of heavy metals in oceans of the world

Metal Open

N.Atlantic

Continental

Coastal

Northern and

Central North sea

Western Atlantic Shelf

Cd 0.002– 0.007 0.04 – 0.068 0.014 – 0.026 0.022

Cu 0.064– 0.096 0.346– 0.666 0.15 – 0.30 0.252

Mn 0.033– 0.073 0.40 – 1.04 0.027 – 0.673 1.155

Another exhaustive study records following values for heavy metals (values in µg/L):

Table - 4.12:: Concentration (µg/l) of heavy metals in oceans of the world

Metal Open ocean Coastal, Bay and Estuary

Cd Pacific = 0.02 – 0.04

Norwegian sea = 0.02 – 0.025

North sea = 0.2 – 0.4

Cr Pacific = 0.06 – 1.26

Mediterranean = 0.07 – 0.97

North sea = 0.4

Cu Pacific = 0.3 – 2.8

North sea = 0.208

Norwegian sea = 0.08 – 0.1

North sea = 2.82 – 9.7

Fe Pacific = 140 – 320 Sea water = 3.2 – 3.4

Pb Pacific = 0.6 – 0.8 North sea = 1.8 – 7.44

Mn Open ocean = 0.018

Hg Atlantic = 0.021 – 0.078

Zn Pacific = 1.9 – 3.0 North sea = 7.0 – 22.0


53

Though, it is observed that values in open oceans are less than those found near the oil

installations, as per data available for the permissible limits of heavy metals in coastal marine water, as

given bellow, it can be safely concluded that the values observed near Bombay High and other fields are

very much below the toxicity limits for metals given in the literature.

Table - 4.13 :: Limits of Heavy metal concentrations

Heavy Metal Limit (ppb) Heavy Metal Limit (ppb)

As 200 Cu 3000

Hg 10 Zn 15000

Pb 2000 Ni 5000

Cd 2000 Mn 2000

Cr 2000 Fe 3000

(Source: Kerala pollution control board: www.keralapcb.org/)

Table - 4.14 :: Heavy metals in sea water

Station Distance Depth Barium Cadmium Chromium Iron Manganese Lead Zinc Mercury

ABBAN from station µg/L µg/L µg/L µg/L µg/L µg/L µg/L µg/L

1

0.5 km

S 2.058 0.261 2.437 48.96 2.408 0 1.961 2.908

M 1.582 0.182 2.346 34.79 1.534 0.37 4.341 7.749

B 1.742 0.273 2.657 35.81 1.498 0 5.369 4.929

2

0.5 km

S 1.51 0.247 2.246 31.83 2.685 0 5.515 4.844

M 2.214 374 2.521 36.49 2.383 0 3.558 19.93

B 1.154 0.265 1.48 23.48 1.847 1.626 3.54 10.12

3

0.5 km

S 1.246 29.24 1.666 27.55 2.014 1.189 10.8 41.65

M 1.2 0.222 1.586 45.9 2.928 1.529 4.31 10.09

B 1.25 0.306 1.637 25.47 2.019 0.902 3.709 7.597

4

1 km

S 1.709 0.307 2.989 32.95 1.771 0.081 4.142 16.67

M 1.608 0.288 2.367 48.6 1.676 0.371 13.18 12.86

B 1.727 0.321 2.497 62.52 2.292 1.074 4.285 5.66

5

1 km

S 1.297 9.208 1.608 21.81 2.734 1.389 4.728 8.942

M 1.35 0.351 1.765 36.75 4.461 2.072 9.043 8.806

B 1.229 0.642 1.65 21.46 2.437 1.826 7.336 7.42

6

1 km

S 1.152 0.277 1.773 24.54 4.095 1.773 2.677 5.171

M 1.397 0.294 1.71 19.59 6.541 2.503 7.441 11.52

B 1.384 0.399 1.788 33.62 9.47 3.305 3.476 8.123

2 km S 2.614 0.395 2.872 57.97 8.334 1.67 12.41 11.89


54

7

M 2.113 0.463 2.422 36.85 7.693 1.613 8.028 7.906

B 1.41 0.307 2.527 38.86 12.31 3.014 3.789 10.66

8

2 km

S 1.592 0.243 2.725 34.67 10.31 1.221 4.821 13.15

M 1.86 0.288 2.348 39.05 8.979 1.327 7.861 8.639

B 1.315 0.26 1.668 42.54 2.226 1.972 4.996 7.81

9

2 KM

S 0.104 828 0.989 21.61 2.947 1.36 2.945 6.47

M 1.48 252.6 1.592 28.49 6.423 2.578 7.363 0

B 1.913 0.452 1.744 28.26 12.59 3.215 6.466 10.09

10

R

S 1.533 0.399 2.132 33.11 11.33 2.974 8.142 9.931

M 2.163 0.323 2.469 42.55 8.569 1.531 8.277 5.803

B 1.913 0.452 1.744 28.26 12.59 3.215 6.466 7.316


Table: 4.14 Heavy metals in sea water (contd.)

Station Distance Depth Barium Cadmium Chromium Iron Manganese Lead Zinc Mercury

GD- CHAYYA

from station µg/L µg/L µg/L µg/L µg/L µg/L µg/L µg/L

S 2.825 0.407 4.449 75.82 8.457 0.833 6.407 10.54

1 0.5 km M 1.115 0.134 1.44 20.55 10.23 0 1.642 6.995

B 2.024 0.482 3.173 45.28 3.297 0.508 12.08 2.213

S 1.637 0.176 3.128 24.68 1.552 0 1.344 8.202

2 0.5 km M 1.159 0.212 1.555 26.8 10.32 2.226 8.017 7.028

B 1.417 0.159 1.528 25.31 1.351 0.211 8.604 10.38

S 1.427 0.202 1.462 19.04 1.323 0 5.657 17.39

3 0.5 km M 1.306 0.15 1.447 39.55 1.681 0.583 4.938 6.973

B 1.297 0.192 1.819 61.99 1.454 1.759 9.217 7.776

S 1.16 0.115 1.474 22.29 1.114 0 4.748 9.406

4 1 km M 1.207 0.184 1.45 18.95 1.424 0.128 1.186 7.992

B 1.891 0.126 1.559 23.28 1.114 0 6.82 2.973

S 1.7 0.275 2.877 32.9 1.121 0 5.565 8.928

5 1 km M 0.961 0.123 1.235 15.81 1.203 0 6.303 7.038

B 3.197 0.696 0.982 1.59 1.63 32.18 0.28 4.449

S 1.121 0.192 1.566 30.36 1.282 0 5.021 7.01

6 1 km M 6.621 2.069 0.749 1.903 1.619 28.09 6.208 6.89

B 1.086 0.175 1.438 28.3 1.096 0.069 3.282 8.88

S 1.902 0.405 3.19 33.31 1.427 0.442 5.899 4.484


55

7 2 km M 1.134 0.077 1.196 14.41 1.06 0 5.926 7.05

B 1.752 0.303 2.736 35.41 3.382 1.056 5.902 6.77

S 2.024 0.411 3.111 32.53 2.087 0.413 9.842 7.718

8 2 km M 1.134 0.077 1.196 14.41 1.06 0 5.926 7.05

B 1.752 0.303 2.736 35.41 3.382 1.056 5.902 6.77

S 2.024 0.411 3.111 32.53 2.087 0.413 9.842 7.718

9 2 KM M 1.374 0.114 1.239 26.7 0 1.291 6.946 8.317

B 1.032 0.144 1.695 24.03 0.646 1.765 1.088 8.012

S 1.322 0.243 1.79 25.77 0.504 2.208 2.661 8.534

10 R M 1.106 0.228 1.666 22.6 0.847 2.7 4.921 6.404

B 1.272 0.186 1.558 28.35 0 1.249 7.754 8.858


Heavy metals in sediments

Heavy metal concentrations in sediments sampled around the installations in Bombay High

South are given in Table 15. Concentrations of Zinc, Copper, Cobalt, Lead, Chromium, Nickel and Barium

are given in units of µg/g (ppm) while that of iron in percentage of dry weight.

Table: 4.15 Heavy metals in sea sediments

Staion Barium Cobalt Chromium Copper Iron Nickel Lead Zinc

ABBAN µg/g µg/g µg/g µg/g %(w/w) µg/g µg/g µg/g

1 0.117 0.008 0.093 0.035 46.9 0.022 0.015 0.027

2 0.111 0.008 0.096 0.039 49.2 0.022 0.017 0.022

4 0.113 0.008 0.092 0.032 46.79 0.021 0.016 0.02

5 0.135 0.009 0.093 0.045 46.1 0.027 0.026 0.026

7 0.105 0.007 0.076 0.03 43.07 0.018 0.022 0.012

8 0.127 0.007 0.075 0.028 40.48 0.021 0.014 0.01

10 0.08 0.006 0.064 0.031 36.04 0.016 0.018 0.01

Table: 4.15 Heavy metals in sea sediments (contd.)

Staion Barium Cobalt Chromium Copper Iron Nickel Lead Zinc

CHAYYA µg/g µg/g µg/g µg/g %(w/w) µg/g µg/g µg/g

1 0.108 0.009 0.078 0.022 40.4 0.037 0.013 0.045


56

2 0.085 0.013 0.076 0.017 38.31 0.054 0.068 0.023

3 0.078 0.018 0.085 0.014 43.79 0.067 0.052 0.016

4 0.074 0.016 0.087 0.013 44.02 0.02 0.036 0.02

5 0.161 0.025 0.149 0.039 82.66 0.067 0.059 0.041

7 0.102 0.012 0.087 0.017 47.02 0.068 0.136 0.033

8 0.097 0.003 0.0991 0.018 46.93 0.054 0.086 0.034

10 0.207 0.032 0.108 0.034 49.13 0.075 0.047 0.045

4.9 BIOLOGICAL MONITORING OF OFFSHORE STATIONS

4.9.1 Methodology of Biological analysis

4.9.1.1 Collection and analysis of Chlorophyll-a

For chlorophyll-a (Chl-a), water samples were collected from surface and bottom according

to the standard protocols. One litre of water from each depth was filtered through GF/F filters (pore size

0.7 µm), and extracted with 10 ml of 90% acetone under cold dark conditions after an extraction period

of 18 to 20 hours. The extract (µg.l-1) was determined using fluorometer. Column Chl-a (mg m-2) was

calculated by integrating the depth values.

4.9.1.2 Collection and analysis of Phytoplankton:

Single celled plant communities floating in the surface water are collectively termed as

phytoplankton. The communities mainly comprise of diatoms and dinoflagellates. They form the first link

in the oceanic food chain. This food web is the most complex as it constitutes of 5 or more links. Almost

entire marine life directly or indirectly depends on the microscopic algae, found at the surface. Due to the

availability of food source, most of the animals either live in this region or migrate towards the surface in

search of food. As such, the top layer of the ocean is considered as most diverse and highly productive.

Diatoms are estimated to contribute up to 45% of the total oceanic primary production (Mann,

1999). Diatoms and dinoflagellates serve as food for the zooplanktons like molluscs, tunicates and also

for small fishes. One of the significant roles of phytoplankton is in the ocean’s carbon cycle. Feeding of

the zooplanktons on these producers marks the entry of photosynthetically fixed carbon into the food

web. This carbon gets accumulated as biomass or detritus or provides energy. Organic matter being

denser than sea water tends to sink, leading to the transport of carbon from surface to the bottom (called

biological pumping) which subsequently acts as food source for bottom living organisms.

Dinoflagellates when present in large number give rise to “red tide” (as the colour of the water

is changed). At such times they are known to produce neurotoxins. These toxins are fatal to fishes and


57

also to the humans consuming such fishes. They can flourish well in phosphate rich conditions (as a

result of anthropogenic activity), as well as in increasing temperatures due to global warming. Hence,

they are also considered as environmental indicator.

Samples were collected 1m below the surface and 2-3 m above the seabed using Niskin

sampler. All the samples were fixed by adding Lugol’s iodine and 5% formalin solution. In laboratory, the

phytoplankton samples were concentrated to 25ml using a siphoning tube. The tube consists of a 10 µm

Nytex filter at one end. This concentrated sample was then taken in 3 aliquots of 1ml each, on Sedgwick-

Rafter Counting Chamber for taxonomic identification and quantification of the phytoplankton (cells per

liter). Olympus BX 41 inverted binocular microscope was used for identification and counting.

The total number of phytoplankton cells present in a litre of water sample calculated using the

formula:

N= n x v x 1000 / V

Where,

N: total number of phytoplankton cells per liter of water filtered.

n: average number of phytoplankton cells in 1 ml of plankton sample.

v: volume of plankton concentrate (ml)

V: volume of total water filtered (l).

Water samples for estimation of chlorophyll were collected from surface and bottom using

Niskin’s sampler. A known quantity of water sample (1 L) was filtered through GF/F Whatman filter paper.

Chlorophyll was extracted using 10ml of 90% acetone in cold condition after a period of 18 – 20 hours.

The acetone extract was read on fluorometer.

The data for the phytoplankton was analyzed using MS-Excel package and Primer. Primer

was mainly used for analyzing diversity. Attempts have been made to estimate the natural variability of

phytoplankton especially that of diatoms and dinoflagellates, in the surface and bottom water.

4.9.1.3 Zooplankton collection and analysis

Zooplankton samples were collected with a modified Heron-Tranter (HT) net; having 0.25m2

mouth areas and 330m mesh size. A calibrated TSK flow meter was fitted at the net mouth to measure

the volume of water filtered. The stratified horizontal vertical haul of 5 minutes in the upper 10-15 m water

depth was sampled. All the samples were preserved in 5% neutralized formaldehyde solution. The

zooplankton biomass was later estimated by displacement volume method and readings were converted

for 100m3. Different zooplankton taxa were sorted from an aliquot of the sample, identified and


58

enumerated under stereoscopic zoom binocular microscope. The numbers were calculated for the whole

samples and given for 100m3 of water.

Sediment sampling for benthic communities, estimation of sediment chlorophyll-a and organic

carbon

Bottom dwelling organisms or benthos were collected, at each stations, by lowering a van

Veen grab. Sub-sampling for meiofauna was done using Plexiglas core of 4.5 cm diameter. The standard

height of corer that is used for sampling is 5 cm. All the sub-samples were preserved in 5% buffered Rose

bengal formalin solution.

Meiobenthos: The meiofauna in the sediment were separated using a 63-micron sieve and placed in plastic bottles

for detailed identification. The meiofauna taxa were picked using a sorting needle and temporary glycerol mounts

were made on glass slides. All specimens were identified up to group level following identification key of Higgins

and Thiel (1988), under a stereo zoom binocular microscope.

Macrobenthos: The sediment samples were collected by van Veen grab (area: 0.11 m-2; Plate 1). Metallic

quadrant of 151510 cm was used for macrofaunal sub sampling from grab sample and preserved in 5% buffered

formalin rose Bengal solution. Aminimum of 2-5 replicates were taken from each station.

All the macrofauna samples were sieved on-board after 48hrs of collection using 500µ size mesh

sieve in filtered seawater and material retained on sieve mesh were fixed in 5% formalin Rose Bengal. In

the laboratory, all the fauna was sorted, identified upto the lower possible level under the microscope.

Biomass (wet weight) was measured by blotting the sample on a blotting paper and weight was taken by

direct weighing on balance. The biomass was calculated in g m-2.

4.9.1.4 Fish & Fishery

Experimental fishing was done along three transects, in the depth zone of 30 - 50 meters.

Fish and shellfish samples were obtained with modified beam trawl, specially designed for deep-water

trawling.

Finfish and shellfish samples were brought in iceboxes to the field laboratory and kept frozen

for further study. Species-wise sorting was done following FAO species identification sheets for fisheries

purposes, western Indian Ocean (Fisher and Bianchi, 1984). Each sorted sample then counted, weighed

and preserved in 70% alcohol for further analysis. Fishes were identified up to species level Species

occurrence (total number of species); abundance (number of fishes and catch rate per hour) was

calculated.


59

4.9.2 Results and Discussion

Location-1 Coordinates: 19006’05” E 70056’26”

Date of sampling: 26th October 2013

Time of sampling: 6:00 - 12:00

Sampling stations 1 2 3 4 5 6 7 8 9 R

Depth in meter 84.6 83.8 84.2 84.7 84.1 84.8 83.5 84.4 84.7 84.2

Secchi disc depth in meter Not measured as sea was rough

Sampling Station Coordinates

Latitude Longitude

RA-1 19007’26” 70056’24”

RA-2 19006’53” 70056’39”

RA-3 19006’32” 70056’37”

RA-4 19005’39” 72014’44”

RA-5 18032’01” 72015’09”


Latitude Longitude

RA-6 18032’12” 72015’21”

RA-7 18031’43” 72016’30”

RA-8 - -

RA-9 18032’12” 72015’50”

RA-10 18037’16” 72016’50”

Biological parameters sea water column around Location -1

Chlorophyll-a

In the sub surface water chlorophyll-a was varying from 1.98-2.83-mg/M3 and in the above

bottom water, chlorophyll –a concentration was varying as 0.55-0.98 mg/m3.

Phytoplankton Population

For evaluation of Phytoplankton population in the surroundings of the Rig ABBAN -4 Sampling

was conducted from 10 sampling locations within 2km radius from the rig. The phytoplankton community

of the sub surface water and above bottom water near the rig was represented by two species Blue green

Algae, (Richelia intracellularis and Trichodesmium sp.),9 species of Diatoms ;10 species of

Dinoflagellates and one member of green algae (Pterosperma sp). Phytoplankton of the sampling stations

at sub surface layer was varying from 166- 210 units/ L with an average of185.2 units/L (SD 16.41).


60

Phytoplankton from the above bottom samples are very high compare to the other installations

sampled. Phytoplankton population from the various locations around Rig was varying from 54-84 units

/L. with an average of 67.6 units/L (SD. 12.06).

Zooplankton Population

Zooplankton sample collected from the sub surface layer in different sampling locations

around the Rig, ABAN-4. Zooplankton population near the rig ABBAN-4 was represented by 8 groups of

plankton; Tintinids, Polychaete worms, Molluscan larvae, Cindaria( Medusa and Polyp). Molluscans,

Urochordata copepods and Arrow worms. Among these holoplankton of this region Protozoans Tintinids

was dominant group followed by Copepods and Urochordata members. The zooplankton density was

varying from 78-130 N/L at an average of 108.8 (S.D-15.78) among these sampling stations. The biomass

of zooplankton by displacement volume was varying from 0.14ml/m3- 0.14 ml/m3.

BENTHIC COMMUNITIES

Chlorophyll content in the sediment

Chrophyll content in the sediment extracted in acetone was below detectable limits.

Benthic organisms

The Mieo benthic organism collected along with sediments by using the Vanveen grabs were

represented by 2 groups of meio fauna , Nematode worms, Polychate worms.The total number of meio

benthic organisms were varying from 0 -0.14/ 10 cm2.The macro benthic organisms were represented by

the same four groups the abundance was varying from11-55 no/M2.

Table: 4.16 (a) :: Phytoplankton variation in abundance and Diversity of marine phytoplankton in sub

surface water between the sampling stations near Location1

Sampling

Station

Surface water Above Bottom water

Abundance

In units/L

No of Species

observed /total

species

% of

diversity

Abundance

In units/

No of Species

observed /total

species

% of

diversity

1 166 20/23 86.95 76 13/23 56.52

2 190 22/23 95.65 78 14/23 60.86

3 210 21/23 91.30 78 16/23 69.56

4 198 19/23 82.60 84 13/23 56.52

5 164 19/23 82.60 72 12/23 52.17

6 200 21/23 91.30 56 13/23 56.52


61

7 170 21/23 91.30 62 12/23 52.17

8 200 19/23 82.60 68 12/23 52.17

9 178 20/23 86.95 48 12/23 52.17

R 176 20/23 86.95 54 13/23 56.52

Table: 4.16(b) Abundance of phytoplankton near Location 1

Installation Surface No of Sampling

location

Group of

phytoplankton

Range

Units/L

Mean

units/L SD

Location-1

Sub surface

10

Blue green algae 50-84 63.6 13.12

Green algae 2-12 5.8 3.58

Diatoms 40-80 64.6 12.03

Dinoflagellates 34-62 51.2 9.43

Total phytoplankton 164-210 185.2 16.41

Above

bottom

10


Green algae 0 0 0

Diatoms 22-48 39.2 8.85



Table: 4.17(a) Variation in abundance and Diversity of marine Zooplankton in sub surface water between the sampling stations near Location 1

Sampling Station Abundance N/L No of Species/ group/total species % of diversity

1 130 15/16 93.75

2 124 14/16 87.5

3 112 12/16 75.0

4 126 14/16 87.5

5 106 14/16 87.5

6 96 12/16 75.0

7 106 13/16 81.25

8 98 14/16 87.5

9 78 14/16 87.5

R 112 16/16 100

Table: 17(b) Abundance of Zooplankton near Rig ABBAN

Installation Surface No of Sampling locations Range N/L Mean N/L SD

Location-1 Sub surface 10 96-130 108.8 15.78


62

Table.4.18: Systematic Account of Phytoplankton in the sea near Location1

GROUP PHYLUM CLASS ORDER FAMILY GENUS/SPECIES #

BLUE GREEN ALGAE

(Desikachary, 1959)

CYANOPHYTA

CYANOPHYCEAEA

NOSTOCALES

NOSTOCACEAE Sub Family Anabanae

Richelia intracellularis

B1

OSCILLATORIACEAE Trichodesmium sp B2

Oscillatoria sp. B3

DIATOMS (Hendey,1937)

BACILLARIOPHYTA CHRYSOPHYTA

BACILLARIOPHYCEAE

ORDER BACILLARIALES Sub Order COSCINODISCACEAE

COSCINODISCACEAE

Coscinodiscus sp. D1

SUB ORDER BIDDULPHINEAE

BIDDULPHIACEAE Eucambia sp. D2

Biddulphia sp. D3

CHATOCERACEAE Chaetoceros costatus D4

SUB ORDER: RHIZOSOLENIINEAE RHIZOSOLENIACEAE Rhizosolenia sp. D5

SUB –ORDER FRAGILARINEAE FRAGILARIACEAE Synreda sp. D6

SUB ORDER NAVICULINEAE

NAVICULACEAE Navicula sp. D7

BACILLARIACEAE Nitzschia sp. D7

DINO FLAGELLATES

PYRROPHYTA

DESMOPHYCEAE

GONYAULACALES

CERATIACEAE

Ceratium breve F1

Ceratium furca F2

Ceratium fusus F3

Ceratium triops F4

CLADOPYXIDACEAE Cladopyxis F5

GONIODOMATACEAE Alexandrium sp. F6

PYROCYSTACEAE Pyrocystis sp. F7

PERIDINIALES PROTOPERIDINIACEAE Protoperidinium sp. F8

NOCTILUCALES NOCTILUCACEAE Naoutiluca F9

GYMNODINIALIS POLYKRIKACEAE Polkrikos sp. F10

GREEN ALGAE CHLOROPHYTA PARSINOPHYCEAE CHLORODENTRALES HALOSPHAERACEAE Pterosperma sp. G1


63

Table: 4.19.Quantitative evaluation of marine phytoplankton in sub surface water near Location-1 GENUS/SPECIES Abundance in units/cells / l of marine water from different sampling stations Rep. by group and individual genus/species

1 2 3 4 5 6 7 8 9 R TOTAL AVG %of Group % Total SD

B BLUE GREEN ALGAE

B1 Richelia intracellularis 32 52 60 64 38 58 46 60 44 48 502 50.2 78.93 27.10 10.47

B2 Trichodesmium sp 4 8 6 10 4 8 6 10 6 8 70 7.0 11.00 3.77 2.16

B3 Oscillatoria sp 6 4 12 10 8 2 4 6 10 2 64 6.4 10.06 3.45 3.50

Total Blue green algae units/l 42 64 78 84 50 68 56 76 60 58 636 63.6 34.34 13.12

I DIATOMS

D1 Coscinodiscus sp. 10 8 2 4 0 4 8 6 2 4 48 4.8 7.43 2.59 3.15

D2 Eucambia sp. 12 4 8 0 2 6 2 8 4 10 56 5.6 8.66 3.02 3.86

D3 Biddulphia sp. 12 10 16 10 8 10 14 12 10 8 110 11.0 17.02 5.94 2.54

D4 Chaetoceros costatus 4 8 12 6 10 14 4 8 12 10 88 8.8 13.62 4.75 3.42

D5 Chaetoceros sp. 6 4 2 2 6 8 10 2 4 2 46 4.6 7.12 2.48 2.84

D6 Rhizosolenia sp. 16 18 12 10 14 8 12 10 12 8 120 12.0 18.57 6.48 3.26

D7 Synreda sp. 12 8 10 4 8 6 12 10 6 2 78 7.8 12.07 4.21 3.32

D8 Navicula sp. 6 4 2 0 0 4 2 8 10 12 48 4.8 7.43 2.59 4.13

D9 Nitzschia sp. 2 4 8 4 2 8 10 8 2 4 52 5.2 8.04 2.80 3.01

Total Datoms units/L 80 68 72 40 50 68 74 72 62 60 646 64.6 34.88 12.03

II DINO FLAGELLATES

F1 Ceratium breve 8 12 10 10 6 8 4 10 12 16 96 9.6 18.75 5.18 3.37

F2 Ceratium furca 4 8 10 12 6 10 2 6 8 4 70 7.0 13.67 3.78 3.16

F3 Ceratium fusus 0 4 0 6 0 10 2 0 4 0 26 2.6 5.08 1.40 3.40

F4 Ceratium triops 8 4 10 6 10 12 8 12 10 12 92 9.2 17.96 4.97 2.69

F5 Cladopyxis 0 4 2 4 0 6 0 0 0 6 22 2.2 4.29 1.18 2.57

F6 Alexandrium sp. 6 2 0 0 10 6 12 8 6 10 60 6.0 11.71 3.24 4.21

F7 Pyrocystis sp. 0 6 8 10 12 8 2 4 4 2 56 5.6 10.93 3.02 3.86

F8 Protoperidinium sp. 4 8 10 6 8 2 4 8 4 2 56 5.6 10.93 3.02 2.79

F9 Naoutiluca 2 0 4 0 2 0 0 0 0 0 8 0.8 1.56 1.56 1.39

F10 Polkrikos sp. 2 6 4 8 2 0 4 0 0 0 26 2.6 5.08 1.40 2.83

Total Dinoflagellates units/L 34 54 58 62 56 62 38 48 48 52 512 51.2 27.65 9.43

G GREEN ALGAE

G1 Pterosperma sp. 10 4 2 12 8 2 2 4 8 6 58 5.8 100 3.13 3.58

Total Green Algae Units/L 10 4 2 12 8 2 2 4 8 6 58 5.8 3.13 3.58

Total phytoplankton units/l 166 190 210 198 164 200 170 200 178 176 185.2 185.2 16.41

Chlorophyll –a Content mg/m3 2.61 2.55 1.98 2.22 2.44 2.17 2.83 2.24 1.98 2.12 0.28


64

Table: 4.20. Quantitative evaluation of marine phytoplankton in above bottom water near Location-1

GENUS/SPECIES Abundance in units/cells / l of marine water from different sampling stations Representation by group and individual genus/species

1 2 3 4 5 6 7 8 9 R TOTAL AVG %of Group % Total SD

B BLUE GREEN ALGAE



B3 Oscillatoria sp 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Total Blue green algae units/l 18 12 18 26 18 10 10 12 16 14 154 15.4 22.78 4.9

I DIATOMS


D2 Eucambia sp. 4 6 2 8 4 2 6 10 6 4 52 5.2 13.26 7.69 2.52

D3 Biddulphia sp. 10 8 12 16 8 12 10 8 4 2 90 9 22.96 13.31 4.02



D6 Synreda sp. 0 0 0 0 2 0 0 0 0 0 2 0.2 0.51 0.29 0.63

D7 Navicula sp. 2 4 2 0 4 2 0 4 2 0 20 2 5.1 2.95 1.63

D8 Nitzschia sp. 10 12 8 6 14 4 4 6 2 4 70 7 17.85 10.35 3.91

Total Datoms units/L 48 48 38 46 48 36 34 42 22 30 392 39.2 8.85

II DINO FLAGELLATES

F1 Ceratium breve 0 0 2 0 0 0 4 2 2 2 12 1.2 9.23 1.77 1.39

F2 Ceratium furca 0 2 2 4 0 0 0 0 0 0 8 0.8 6.15 1.18 1.39

F3 Ceratium fusus 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

F4 Ceratium triops 4 6 6 4 2 6 8 10 4 2 52 5.2 40 7.69 2.53

F5 Cladopyxis 0 0 4 0 0 0 0 0 0 0 4 0.4 3.08 0.59 1.26

F6 Alexandrium sp. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

F7 Pyrocystis sp. 2 4 4 2 0 2 0 0 2 4 20 2 15.38 2.96 1.63


F9 Naoutiluca 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

F10 Polkrikos sp. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Total Dinoflagellates units/L 10 18 22 12 6 10 18 14 10 10 130 13 100 69.08 12.56

G GREEN ALGAE

G1 Pterosperma sp. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Total Green Algae Units/L 0 0 0 0 0 0 0 0 0 0 0 0 0 0

TOTAL PHYTOPLANKTON UNITS/L 76 78 78 84 72 56 62 68 48 54 676 67.6 - 12.06

CHLOROPHYLL –a Content mg/m3 0.98 0.78 0.67 0.55 0.66 0.9 0.9 0.8 0.64 0.6 0.14


65

Table: 4.21. Systematic account of marine zooplankton in the subsurface water near –Location1


TINTINIDS PROTOZOA

CILIOPHORA

SPIROTRICHEA TINTINNIDA TINTINNIDAE Eutintinnus sp. T1

Amphorides sp..

XYSTONELLIDAE Favella SP.

POLYCHAETE WORMS

ANNELIDA POLYCHAETA PHYLLODOCIDA LOPADORHYNCHIDAE Lopadorhynchus sp.

P1

MOLLUSCANS MOLLUSCA GASTROPODA MESOGASTROPODA ATLANTIDAE Atlanta sp. MO1

COPEPODS

ARTHROPODA

CRUSTACEA

SUB CLASS COPEPODA

CALANOIDA CALANIDAE Canthocalanus sp. C1

ACARTIIDAE Acartia sp. C2

CENTROPAGIDAE Centropages sp. C3

CYCLOPOIDA ONCAEIDAE Oncaea sp. C4

HARPACTICOIDA ECTINOSOMATIDAE Microsetella sp. C5

POLYP CNIDARAIA HYDROZOA

HYDROIDA

THECATA CAMPANULARIIDAE Clytia sp. P1

HYDROIDOMEDUSAE CNIDARAIA HYDROZOA

Proboscoida Campanulariidae Obelia sp. M1

UROCHORDATA CHORDATA

SUB PHYLUM UROCHORDATA

APPENDICULARIA OIKOPLEURIDAE Oikopleura sp. U1

FRITILLARIIDAE Fritillaria sp. U2

ARROW WORMS CHAETOGNATHA SAGITTOIDEA APHRAGMOPHORA SAGITTIDAE Sagitta sp. A1

NUPLIUS LARVAE ARTHROPODA

SUB PHYLM CRUSTACEA

COPEPODA - - Nauplius larvae L1


66

Table.4.22: Quantitative evaluation of marine zooplankton in sub-surface water near Location1

GENUS/SPECIES Abundance in n/l marine water from different sampling stations Representation by group and individual genus/species

1 2 3 4 5 6 7 8 9 R TOTAL AVG % of Group % of Total SD

T TINTINIDS

T1 Eutintinnus sp. 22 14 16 30 14 18 20 24 12 16 186 18.6 51.38 17.09 5.50

T2 Amphorides sp.. 12 10 8 12 18 6 10 12 8 10 106 10.6 29.28 9.74 3.27

T3 Favella SP. 4 8 10 6 12 4 2 8 10 6 70 7.0 19.34 6.43 3.16

Total Tininids N/L 38 32 34 48 44 28 32 44 30 32 362 36.2 33.27 6.89

P POLYCHAETE WORMS

P1 Lopadorhynchus sp. 2 4 4 2 2 6 2 2 4 4 32 3.2 100 2.94 1.39

Polychaete worms N/L 2 4 4 2 2 6 2 2 4 4 32 3.2 2.94 1.39

MO MOLLUSCANS

MO1 Atlanta Sp. 4 0 0 2 0 0 0 2 0 6 14 1.4 100 1.29 2.11

Molluscans total N/L 4 0 0 2 0 0 0 2 0 6 14 1.4 1.29 2.11

C COPEPODS

C1 Canthocalanus sp. 8 2 6 4 2 4 6 2 4 2 40 4.0 12.19 3.67 2.10

C2 Acartia sp. 10 14 8 18 6 12 10 4 6 8 96 9.6 29.27 8.82 4.19

C3 Centropages sp. 4 2 4 2 2 2 8 2 4 6 36 3.6 10.98 3.30 2.06

C4 Oncaea sp. 12 16 10 8 12 6 12 10 4 8 98 9.8 29.88 9.00 3.45

C5 Microsetella sp. 6 8 12 4 10 4 6 2 2 4 58 5.8 17.68 5.33 3.32

Total copepods N/L 40 42 40 36 32 28 42 20 20 28 328 32.8 30.14 8.54

MY CNIDARAIA

MY1 Clytia sp. 4 2 2 4 2 2 6 2 2 2 28 2.8 77.77 2.57 1.39

MY2 Obelia sp. 0 0 0 2 0 0 0 0 2 4 8 0.8 22.22 0.74 1.39

Total cindarians N/L 4 2 2 6 2 2 6 2 4 6 36 3.6 3.30 1.69

UROCHORDATA

U1 Oikopleura sp. 10 8 6 4 2 4 8 4 6 2 54 5.4 72.97 4.96 2.67

U2 Fritillaria sp. 4 2 0 0 4 4 0 2 2 2 20 2.0 27.03 1.84 1.63

Total Urochordata N/L 14 10 6 4 6 8 8 6 8 4 74 7.4 6.80 2.98

A ARROW WORMS CHA ETOGNATHA

A1 Sagitta sp. 2 4 0 0 2 4 2 0 0 2 16 1.6 100 1.47 1.57

ARROW WORMS TOTAL NO/L 2 4 0 0 2 4 2 0 0 2 16 1.6 1.47 1.57

L NUPLIUS LARVAE

L1 Nauplius larvae of Copepods 26 30 26 28 18 20 14 22 12 30 226 22.6 100 20.77 6.46

LARVAE TOTAL N/L 26 30 26 28 18 20 14 22 12 30 226 22.6 20.77 6.46

ZOOPLANKTON TOTAL N/L 130 124 112 126 106 96 106 98 78 112 1088 108.8 15.78

BIOMASS DISPLACMENT VOLUMEml / m3 0.14 0.12 0.12 0.12 0.12 0.10 0.12 0.14 0.12 0.12 0.011


67

Table.4.23 Quantitative evaluation of macro fauna near the near Location-1

TAXA

ABUNDANCE IN N/M2 DIFFERENT SAMPLING STATIONS REPRESENTATION BY GROUP

1 2 3 4 5 6 7 8 9 R TOTAL MEAN % OF

COMPOSITION SD

POLYCHATES 11 22 11 0 0 11 22 0 11 11 99 9.9 32.24 8.12

NEMATODES 11 11 22 11 0 0 22 11 11 32 131 13.1 42.67 9.89

CRUSTACEANS 0 0 22 0 11 22 0 22 0 0 77 7.7 25.08 10.43

TOTAL NUMBERS

N/ m2 22 33 55 11 11 33 44 33 22 44 307 30.7 14.48

BIOMASS gm/m2

4.17 4.46 8.75 0.75 2.73 6.08 7.1 3.41 4.19 5.26 2.26

Table 4.24 Macro fauna taxon diversity near the rig – Abban

STATION NUMBER OF TAXA TOTAL DENSITY N/m2 % OF DIVERSITY

1 2/3 22 66.6

2 2/3 33 66.6

3 3/3 55 100

4 1/3 11 33.3

5 1/3 11 33.3

6 2/3 33 66.6

7 2/3 44 66.6

8 2/3 33 66.6

9 2/3 22 66/6

R 2/3 44 66.6

Location-2

Geographical coordinates :: 19014’26” E 70058’52”N

Date of sampling: 26th October, 2013 Time of sampling: 14:00-

19:30

Sampling Stations 1 2 3 4 5 6 7 8 9 R

Depth in meter 79 78.8 79.7 79.4 78.7 79.4 79.4 78.9 79.3 78.3

Sechi disc

depth in meter Not measured as sea was rough

R – Reference station


68


Latitude Longitude

RGD-1 19038’06” 71024’51”

RGD-2 19037’33” 71024’40”

RGD-3 19037’17” 71024’43”

RGD-4 19036’03” 71023’42”

RGD-5 19036’31” 71024’17”


Latitude Longitude

RGD-6 19036’46” 71024’28”

RGD-7 19036’20” 71025’50”

RGD-8 19036’41” 72025’22”

RGD-9 19036’47” 72025’03”

RGD-10 19038’16” 72028’47”

Biological parameters in sea water column around Location-2

Chlorophyll-a

In the sub surface water chlorophyll-a was varying from 1.98-2.83-mg/M3 and in the above

bottom water chlorophyll –a concentration was below detectable limit.

Phytoplankton Population

For evaluation of Phytoplankton population in the surroundings of the Rig G.D Chayya.

Sampling was conducted from 9 sampling locations within 2km radius from the rig. The phytoplankton

community of the sub surface water and above bottom water near the rig was represented by two species

Blue green Algae, (Richelia intracellularis, Trichodesmium sp.),9 species of Diatoms and 10 species of

Dinoflagellates. Phytoplankton of the sampling stations at sub surface layer was varying from 178-254

units/ L with an average of 211.2 units/L (SD 23.70).

Blue green algae Richelia intracellularis was present in large number in the sub surface water

along with one associated diatom Rhizosolenia sp. These two algae were the dominant among the

phytoplankton in the surface water around these region. Phytoplankton from the above bottom samples

the various locations around Rig was very low varying from 24-58 units /L. with an average of 44.0 units/L

(SD. 11.07).

Zooplankton Population

Zooplankton samples were collected from the sub surface layer in different sampling locations

around the Rig G.D. Chayya. Zooplankton population near the rig was represented by 6 groups of

plankton; Tintinids copepods, Cindararians (medusa and polyp), Urochordata members and arrow

worms. Among these, Protozoans Tintinids was dominant group followed by Copepods, The zooplankton

density was varying from 56-100 No/L with an average value of 81.2 N/L (S.D-14.70) among the sampling

stations. The biomass of zooplankton by displacement volume was varying from 0.02ml/m3- 0.05 ml/m3.


69

BENTHIC COMMUNITIES

Chlorophyll content in the sediment

Chlorophyll content in the sediment extracted in acetone was below detectable limits.

Benthic organisms

The Mieo benthic organism collected along with sediments by using the Vanveen grabs were

represented by 2 groups of meio fauna, Nematode worms, Polychaete worms, The total number of meio

benthic organisms were varying from 0 -0.06 / 10 cm2.The macro benthic organisms were represented

by Nematode worms, Polychaete worms and crustaceans groups but the abundance was s varying from

11 -55 no/M2.

Table: 24 (a) Phytoplankton variation in abundance and Diversity in subsurface and above bottom water

between the sampling stations near Location-2

Sampling

Station

Surface water Above Bottom water

Abundance

In units/L

No of Species observed

/total species

% of diversity Abundance

In units/L

No of Species observed

/total species

% of diversity

1 232 20/22 90.90 58 10/22 45.45

2 218 18/22 81.81 60 9/22 40.90

3 188 18/22 81.81 50 9/22 40.90

4 202 16/22 72.72 42 6/22 27.27

5 188 19/22 86.36 46 7/22 31.81

6 254 17/22 77.27 38 7/22 31.81

7 222 16/22 72.72 38 5/22 22.72

8 228 17/22 77.27 50 6/22 27.27

9 202 14/22 63.63 24 5/22 22.72

R 178 15/22 68.18 34 5/22 22.72


70

Table: 24 (b) Abundance of phytoplankton near Location2

Installation Surface No of Sampling location

Group of phytoplankton

Range Units/L

Mean units/L

SD

Rig

G.D hayya (Loc-2)

Sub surface 10



Diatoms 72-114 91.4 10.28



Above bottom 10



Diatoms 10-26 16.8 4.99



Table: 25 (a) Variation in abundance and Diversity of marine Zooplankton in sub surface water between

the sampling stations near Installation Location -2

Sampling

Station

Abundance N/L No of Species/ group/total species

% of diversity

1 80 17/20 85

2 94 18/20 90

3 82 17/20 85

4 66 14/20 70

5 56 17/20 85

6 64 16/20 80

7 86 15/20 75

8 90 16/20 80

9 94 16/20 80

R 100 18/20 90

Table: 25 (b) Abundance of Zooplankton near Location-2

Installation Surface No of Sampling locations

Range

N/L

Mean

N/L

SD

Rig

G.D Chayya (Loc-2)

Sub surface 10 56-100 81.2 14.70


71

Table: 4.26: Systematic account of marine phytoplankton in the subsurface water in the sea near Location-2


BLUE GREEN

ALGAE (Desikachary,

1959)

CYANOPHYTA

CYANOPHYCEAEA

NOSTOCALES

NOSTOCACEAE Sub Family Anabanae

Richelia intracellularis

B1

OSCILLATORIACEAE Trichodesmium sp B2

DIATOMS (Hendey,1937)

BACILLARIOPHYTA CHRYSOPHYTA

BACILLARIOPHYCEAE

ORDER BACILLARIALES Sub Order

COSCINODISCACEAE COSCINODISCACEAE Coscinodiscus sp. D1

SUB ORDER BIDDULPHINEAE

BIDDULPHIACEAE Eucambia sp. D2

Biddulphia sp. D3

CHATOCERACEAE Chaetoceros costatus D4

Chaetoceros sp. D5

SUB ORDER: RHIZOSOLENIINEAE

RHIZOSOLENIACEAE Rhizosolenia sp. D6

SUB –ORDER FRAGILARINEAE

FRAGILARIACEAE Synreda sp. D7

SUB ORDER NAVICULINEAE

NAVICULACEAE Navicula sp. D8

BACILLARIACEAE Nitzschia sp. D9

DINO FLAGELLATES

PYRROPHYTA

DESMOPHYCEAE

GONYAULACALES

CERATIACEAE

Ceratium breve F1

Ceratium furca F2

Ceratium fusus F3

Ceratium triops F4

CLADOPYXIDACEAE Cladopyxis F5

GONIODOMATACEAE Alexandrium sp. F6

PYROCYSTACEAE Pyrocystis sp. F7

PERIDINIALES PROTOPERIDINIACEAE Protoperidinium sp. F8

NOCTILUCALES NOCTILUCACEAE Naoutiluca F9

GYMNODINIALIS POLYKRIKACEAE Polkrikos sp. F10

GREEN ALGAE CHLOROPHYTA PARSINOPHYCEAE CHLORODENTRALES HALOSPHAERACEAE Pterosperma sp. G1


72

Table: 4.27: Quantitative evaluation of marine phytoplankton in sub surface water near Location-2

GENUS/SPECIES Abundance in units/cells / l of marine water from different sampling stations Rep. by group and individual genus/species

1 2 3 4 5 6 7 8 9 R TOTAL AVG %of Group. % Total SD

B BLUE GREEN ALGAE



Total Blue green algae units/L 72 56 46 86 52 78 82 88 68 48 676 67.6 15.22

I DIATOMS


D2 Eucambia sp. 8 10 4 12 6 10 8 12 10 2 82 8.2 8.97 3.88 3.15

D3 Biddulphia sp. 12 14 10 10 6 4 16 12 14 12 110 11.0 12.03 5.21 3.49


D5 Chaetoceros sp. 8 0 0 4 0 0 0 0 0 0 12 1.2 1.31 0.56 2.56


D7 Synreda sp. 4 0 12 2 4 6 0 0 0 2 30 3.0 3.28 1.42 3.60

D8 Navicula sp. 12 8 6 2 4 12 6 4 2 4 60 6.0 6.56 2.84 3.46

D9 Nitzschia sp. 10 12 8 10 12 16 10 14 8 6 106 10.6 11.59 5.02 2.83


II DINO FLAGELLATES

F1 Ceratium breve 10 12 8 10 16 14 22 10 14 8 124 12.4 27.55 5.87 4.08

F2 Ceratium furca 4 4 2 0 2 4 10 4 0 0 30 3.0 6.66 1.42 2.86

F3 Ceratium fusus 2 0 6 0 6 0 4 6 0 0 24 2.4 5.33 1.14 2.65

F4 Ceratium triops 6 8 2 4 6 4 0 2 6 10 48 4.8 10.66 2,27 2.86

F5 Cladopyxis 0 4 0 0 2 0 0 0 0 0 6 0.6 1.33 0.28 1.28

F6 Alexandrium sp. 4 6 2 0 8 4 6 10 6 4 50 5.0 11.11 2.36 2.72

F7 Pyrocystis sp. 0 4 0 0 0 0 0 0 0 0 4 0.4 0.88 0.19 1.2


F9 Naoutiluca 4 0 8 2 0 6 0 0 0 0 20 2.0 4.44 0.94 2.82

F10 Polkrikos sp. 6 12 8 6 4 10 12 4 8 2 72 7.2 16 3.41 3.24


G GREEN ALGAE

G1 Pterosperma sp. 6 10 6 12 4 8 4 10 2 10 72 7.2 100 3.41 3.12

Total Green Algae Units/L 6 10 6 12 4 8 4 10 2 10 72 7.2 100 3.41 3.12

Total phytoplankton units/l 232 218 188 202 188 254 222 228 202 178 2112 211.2 23.70

CHLOROPHYLL –a Content mg/m3

2.61 2.55 1.98 2.22 2.44 2.17 2.83 2.24 2.12 1.98 0.28


73

Table.4.28: Quantitative evaluation of marine phytoplankton in above bottom water near Location-2

GENUS/SPECIES Abundance in units/cells / l of marine water from different sampling stations Representation by group and individual genus/species

1 2 3 4 5 6 7 8 9 R TOTAL AVG %of Group. % Total SD

B BLUE GREEN ALGAE



Total Blue green algae units/l 10 22 12 16 18 10 12 16 8 10 134 13.4 4.2

I DIATOMS


D2 Eucambia sp. 0 2 0 0 0 0 0 0 0 0 2 0.2 1.19 0.45 0.6

D3 Biddulphia sp. 6 8 2 10 4 2 0 4 2 6 44 4.4 26.19 10.0 2.93

D4 Chaetoceros costatus 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

D5 Chaetoceros sp. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0


D7 Synreda sp. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

D8 Navicula sp. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

D9 Nitzschia sp. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0


II DINO FLAGELLATES

F1 Ceratium breve 8 2 6 0 4 6 4 6 2 2 40 4.0 30.30 9.09 2.36

F2 Ceratium furca 2 6 6 4 2 2 8 2 2 2 36 3.6 27.27 8.18 2.15

F3 Ceratium fusus 0 0 2 0 4 0 0 0 0 0 6 0.6 4.54 1.36 1.28

F4 Ceratium triops 4 4 4 4 0 0 4 0 0 0 20 2.0 15.15 4.54 2.0

F5 Cladopyxis 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

F6 Alexandrium sp. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

F7 Pyrocystis sp. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0


F9 Naoutiluca 2 0 0 0 0 4 0 0 0 0 6 0.6 4.54 1.36 1.28

F10 Polkrikos sp. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0


G GREEN ALGAE

G1 Pterosperma sp. 4 0 0 2 0 0 0 0 0 0 6 0.6 100 1.36 1.28

Total Green Algae Units/L 4 0 0 2 0 0 0 0 0 0 6 0.6 - - 1.28

Total phytoplankton units/l 58 60 50 42 46 38 38 50 24 34 440 44.0 - - 11.07

Chlorophyll –a Content mg/m3 ND ND ND ND ND ND ND ND ND ND 0.26


74

Table - 4.29: Systematic account of marine zooplankton in the subsurface water near Location-2


TINTINIDS PROTOZOA CILIOPHORA

SPIROTRICHEA TINTINNIDA TINTINNIDAE Eutintinnus sp. T1

Amphorides sp..

XYSTONELLIDAE Favella SP.

RHABDONELLIDAE Rhabdonella sp.

CODONELLIDAE Tintinnopsis acuminata

COPEPODS

ARTHROPODA

CRUSTACEA

SUB CLASS COPEPODA

CALANOIDA CALANIDAE Canthocalanus sp. C1

ACARTIIDAE Acartia sp. C2

CENTROPAGIDAE Centropages sp. C3

CYCLOPOIDA ONCAEIDAE Oncaea sp. C4

HARPACTICOIDA ECTINOSOMATIDAE Microsetella sp. C5

POLYP CNIDARAIA HYDROZOA HYDROIDA

THECATA CAMPANULARIIDAE Clytia sp. P1

HYDROIDOMEDUSAE CNIDARAIA HYDROZOA

Proboscoida Campanulariidae Obelia sp. M1

UROCHORDATA CHORDATA SUB PHYLUM

UROCHORDATA

APPENDICULARIA OIKOPLEURIDAE Oikopleura sp. U1

FRITILLARIIDAE Fritillaria sp. U2

ARROW WORMS CHAETOGNATHA SAGITTOIDEA APHRAGMOPHORA SAGITTIDAE Sagitta sp. A1

NUPLIUS LARVAE ARTHROPODA SUB PHYLM CRUSTACEA

COPEPODA - - Nauplius larvae L1


75

Table.4.30: Quantitative evaluation of marine zooplankton in sub surface water near Location-2

GENUS/SPECIES Abundance in n/l marine water from different sampling stations Representation by group and individual genus/species

1 2 3 4 5 6 7 8 9 R TOTAL AVG % of Group % of Total SD

T TINTINIDS

T1 Eutintinnus sp. 8 6 10 4 2 10 6 8 10 12 76 7.6 32.47 9.36 2.93

T2 Amphorides sp.. 0 2 0 0 0 0 4 0 0 6 12 1.2 5.13 1.48 2.04

T3 Favella SP. 4 10 6 2 4 2 6 10 2 4 50 5.0 21.37 6.16 2.86

T4 Rhabdonella sp. 2 0 0 2 6 4 0 0 0 2 16 16 6.84 1.97 1.95

T5 Tintinnopsis acuminata 10 8 12 6 4 2 8 12 10 8 80 8.0 34.18 9.85 3.09

Total Tininids N/L 24 26 28 14 16 18 24 30 22 32 234 28.82 5.66

C COPEPODS

C1 Canthocalanus sp. 4 8 6 2 4 6 10 6 12 6 64 6.4 21.33 7.88 2.8

C2 Acartia sp. 6 12 2 4 2 6 6 4 10 12 64 6.4 21.33 7.88 3.55

C3 Centropages sp. 2 4 2 0 2 2 0 6 8 4 30 3.0 10.0 3.69 2.40

C4 Oncaea sp. 10 6 8 12 6 2 8 12 4 2 70 7.0 23.33 8.62 3.49

C5 Microsetella sp. 8 6 6 10 4 2 6 8 10 12 72 7.2 24.0 8.86 2.85

Total copepods N/L 30 36 24 28 18 18 30 36 44 36 300 30.0 - 36.94 7.95

M CNIDARAIA

M1 Clytia sp. 2 0 2 0 0 0 0 0 0 2 6 0.6 75.0 0.74 0.92

M2 Obelia sp. 0 2 0 0 0 0 0 0 0 0 2 0.2 25.0 0.25 0.6

Total cindarians N/L 2 2 2 0 0 0 0 0 0 2 8 0.8 - 0.98 0.98

U UROCHORDATA

U1 Oikopleura sp. 6 10 8 12 6 8 10 2 8 10 80 8.0 83.33 9.85 2.68

U2 Fritillaria sp. 0 4 2 0 4 0 0 4 2 0 16 1.6 16.67 1.97 1.74

Total Urochordata N/L 6 14 10 12 10 8 10 6 10 10 96 9.6 - 11.82 2.33

A ARROW WORMS CHA ETOGNATHA

A1 Sagitta sp. 2 4 2 0 2 6 2 4 2 2 26 2.6 100 3.20 1.56

ARROW WORMS TOTAL NO/L 2 4 2 0 2 6 2 4 2 2 26 2.6 - 3.20 1.56

L NUPLIUS LARVAE

L1 Nauplius larvae of Copepods 16 12 16 12 10 14 20 14 16 18 148 14.8 100 18.23 2.85

LARVAE TOTAL N/L 16 12 16 12 10 14 20 14 16 18 148 14.8 - 18.23 2.85

ZOOPLANKTON TOTAL N/L 80 94 82 66 56 64 86 90 94 100 812 81.2 - 14.70

BIOMASS DISPLACMENT VOLUMEml / m3

0.04 0.04 0.03 0.02 0.03 0.04 0.05 0.04 0.04 0.05 - - - - 0.008

76

Table.4.31: Quantitative evaluation of macro fauna on rig near Location2

TAXA

ABUNDANCE IN N/M2 DIFFERENT SAMPLING STATIONS REPRESENTATION BY GROUP

1 2 3 4 5 6 7 8 9 R TOTAL MEAN % OF

COMPOSITION SD

POLYCHATES 0 0 11 0 11 22 0 11 11 11 77 7.7 27.02 7.42

NEMATODES 22 11 32 11 11 22 11 0 22 22 164 16.4 57.54 9.15

CRUSTACEANS 0 0 11 0 0 11 0 0 0 22 44 4.4 15.44 7.69

TOTAL NUMBERS NO/

m2 22 11 54 11 22 55 11 11 33 55 285 28.5 - 19.39

BIOMASS gm/m2

3.01 1.39 5.68 1.82 4.60 8.66 1.39 1.07 4.03 7.21 2.64

Table.4.32: Macro fauna taxon diversity of the rig Near Location-2

Station Number Of Taxa Total Density No/m2 % Of Diversity

1 1/3 22 33.3

2 1/3 11 33.3

3 3/3 54 100

4 1/3 11 33.3

5 2/3 22 66.6

6 3/3 55 100

7 1/3 11 33.3

8 1/3 11 33.3

9 2/3 33 66.6

R 3/3 55 100

Fish and Fisheries

Coastal fishery is an important commercial activity as it plays a vital role in regional and

national economy of a maritime state. However, coastal fishery is facing many problems largely due to

the increased level of pollution and management. It has been successfully demonstrated that coastal

pollution can seriously affect the fishable stocks. Consequently, significant efforts are put in assessing

fishery resources both on the regional as well as local level. In this context, the presence or absence of

particular fish species and their standing stock has been widely used as a biological indicator of the

degree of pollution.

The success of any fishery depends upon the prevailing' physicochemical and biological

conditions and hence the study of environmental factors is important for the assessment of fishery

77

resources. The effect of effluent or waste disposal in the aquatic environment inevitably includes

modifications and changes in the physico-chemical and biological characteristics of the ecosystem.

These changes are more pronounced in the semi-enclosed water bodies such as estuaries and bays

where water circulation is limited. The toxic effluent once discharged into the environment produces

characteristic response and sometimes mortality among the biota including fish and fishery. Such

responses can be measured on the biological scale. Hence, evaluation of biological productivity

(microbes, phytoplankton, zooplankton and benthos) of an ecosystem is an integral part of any

environmental impact assessment. Such studies are concerned with identifying, predicting and evaluating

the environmental effects of waste water/effluent discharge. It employs the scientific methodologies and

techniques for collecting baseline data which at later stage will be useful in planning and decision making.

Experimental fishing was done along two transects, at 30~ 50 m water depth zone Finfish and

shellfish samples were brought in iceboxes to the field laboratory and kept deep frozen for identification.

Samples of each species were sorted, counted and weighed. Fishes were identified up to species level

following FAO species identification sheets for fisheries purposes, western Indian Ocean (Fisher and

Bianchi, 1984). Species occurrence (total number of species), abundance (number of fishes and catch

rate per hour) were calculated.

Abundance and density

The relative abundance (total fish number and biomass) and number of demersal fishes

caught in the selected area is presented below. A catch rate of 120 kg/hr and 65 kg/hr was obtained in

depth zones of 50 m and 30 m, respectively. Even though the weight was higher, trawl catch obtained

from 50 m depth zone was of poor quality and mainly consisted of gastropods, jellyfish etc., Hence, only

catch from 30 m depth zone was considered for detailed fishery assessment.

Species Occurrence

The fish community was typical of Indio-Pacific type. The demersal fish assemblage was

dominated in terms of abundance by members of the family, Penaeidae (19.4%), Trichiuridae (16.2%),

Portunidae (15%) Scienidae (14%), Synodontidae (7%), Leognanthidae (5.8%) and Cynoglossidae

(5.4%) were the main contributos. Others such as families Tetradontidae, Carcharinidae together

contributed to the remainder of the catch (~ 13%). Different crustacean and molluscan species were

recorded in the trawl catch. Amongst crustaceans, prawns were the most dominant. Prawns belonging to

family Penaeidae, Solenoceridae, Sergestidae, Sicyonidae consistently occurred. Crustacean species in

order to the abundance were Acetus Indiicus, Deep sea shrimp, Solenocera sp. and Metapenaeus sp

and crab species (Porunus sp. and Charybdis sp.). While two species Charybdis annulata and

Cryptopodia angulata were reported first time from the Mumbai High region.

78

The high population density of bottom fauna (demersal fish and benthos) in the study area

reflects on the high biological productivity and rich fishing grounds. The occurrence of large number of

juveniles in the trawl samples indicate that the area may serve as nursery ground for commercially

important fin and shellfishes. Furthermore, high occurrence of decapod larvae, fish eggs and larvae in

zooplankton samples substantiates it. The mean catch rate of 80 kg/hour is well comparable to some of

the nearshore fishing grounds along the west coast of India (Parulekar et al., 1982).

Table 4.33: Relative abundance in the fishes during the sampling

# Scientific name Common name Relative abundance

no/Haul

Relative Biomass gm/ haul

1 Combionella buitendijki Jelly fish 20 -

2 Octopus sp. Octopus 12 3500

3 Sepia elliptica Cuttle Fish 7 560

4 Loligo duvauceli Indian squid 4 450

5 Penaeus indicus Indian White Prawn 12 1000

4 Penaeus monodon TigerPrawn 20 800

5 Eugomphodus Taurus Sand Tiger Shark 2 1400

6 Carcharhinus dussumieri White Cheeked Shark

1 1100

7 Sardinella longiceps Sardine 12 1800

8 Congresox telabonoides Common Ell 2 600

9 Hardpodon nehereus Bombay Duck 32 3000

10 Trichiurus lepturus Ribbon Fishes 4 400

11 Lepturacanthus savla Ribbon Fishes 2 300

12 Arius sp. Arius sp. 4 1500

13 Rastrelliger kanagurta Indian Mackerel 10 2500

79

Chapter 5

ANTICIPATED ENVIRONMENTAL IMPACTS

& MITIGATION MEASURES

5.1. ENVIRONMENTAL IMPACTS IDENTIFIED:

This section identifies and attempts at assessing the aspects arising due to drilling activity which may

have environmental (Physical and Biological). The following factors which were analyzed for the impact

study based on secondary data constituting the baseline study of.

Offshore air and noise quality

Marine water quality & temperature

Biological environment

Benthic community

Marine micro-organisms, fish, reptiles, mammals, seabirds

Marine ecology

Occupational safety of personnel

Environmental aspects (based on phases of activities pre drilling, drilling, decommissioning

and potential accidental events) and impacts on offshore environment have been taken into consideration

in line with standard management system terminology. It is imperative that an environmental or socio-

economic impact may result from any of the project activity.

Disposal of Drill Cuttings and Residual WBM:

Drill cuttings, composed of rocky substrate like shale, clay, sandstone, etc. are produced

during the drilling process and are separated from the mud. Typically, the solid medium used in the drilling

mud is barite (barium sulfate) as weighing agent, with bentonite clays as a thickener. Drilling mud also

contains a number of chemicals that are added depending on down-hole formation conditions.

Thoroughly washed drill cuttings are dispersed into the sea.

ONGC instituted a study on the drill cuttings and their toxicity through CRRI (Central Road

Research Institute, New Delhi) which reveals that there is no toxicity in any of the samples

of drill cuttings analyzed and the drill cuttings were found to be inert in nature.

80

Mud system analyses data has been found to be much below the prescribed toxicity limit;

the relevant portion from the report published by Institute of Drilling Technology, ONGC,

Dehradun is annexed at Annexure – IV at the end of the report.

Impacts on Marine Water and Sediment as given below.

5.1.1. Impacts on Marine Water and Sediment:

Number of activities related to various phases of the proposed drilling activity has the potential

to impact marine water quality and consequently marine ecology adjacent to the drilling locations. Some

marine water quality impacts will also occur along corridors that are proposed to be used for providing

logistic support to the drilling rig, though they are anticipated to be minimal. Some near shore activities

like handling of chemicals and oil may also impact marine environment. The important potential

anticipated impacts to marine environment are discussed under the following major heads:

Physical presence of the drilling rig

Disposal of drill cuttings and WBM

Operational discharges like sanitary waste water, washing fluids (deck drainage, rig floor

washing, etc.,), cooling water,, etc.,

Non-routine discharges that may be caused by ballast water, chemical spills, etc.

Food waste and residuals.

Impacts on Marine Water Quality:

The main physical impacts on seawater from the discharge of cuttings and drilling fluids are

associated with a localized increase in water turbidity (due to increase in suspended solids) in the vicinity

of discharge point and minor changes in local water quality.

Impact on Benthic Fauna:

The main impact on benthic fauna will be from physical smothering and restricted to areas

where cuttings are deposited. Studies suggest that biological effects of WBM contaminated cuttings will

be confined within 100 m from well location (Effects of Exploratory Drilling Discharges on the Benthos.

Gillmor R. B. Et al.). Re-colonization of biota and recovery will be well established within a year after

disposal has stopped.

Under less energetic wave and current conditions, impacts recovery may take more time;

however taking into account that project site is located in high waters of Arabian Sea characterized by a

high energy environment, impacts on benthos due to smothering and physical disturbance are anticipated

to be minimal and of short duration.

Toxic effects on marine species of this substratum are also not anticipated due to low toxicity

of mud formulation to be used for the proposed project. Data from previous studies indicate that major

81

biological changes in benthic communities mostly extend to a maximum of 500 – 1000 m (GESAMP,

1993); in addition to minor detectable changes extending to a maximum of about 3 – 5 km from the drilling

location (Gray et al., 1999).

Discharge of Grey and Black Water

It is estimated that Drilling rig operations will result in the generation of about 10 m3/day of

sewage and wastes from kitchen, shower and laundry area. Sewage will be subsequently discharged

into marine environment after passing it through a screen less than 25 mm diameter prior to discharge.

It is likely that such discharge can result in localized organic enrichment in the vicinity of the discharge

point that in turn can result in potential oxygen depletion in the discharge plume resulting in some minor

disturbance to the marine ecosystem close to point of discharge - treatment/maceration of effluents will

be carried out in compliance with MARPOL 73/78 requirements.

Water currents would also assist dilution and dispersion of discharged material and would

eventually restore oxygen and nutrient levels to background conditions. Impacts on marine water quality

and marine organisms are therefore considered to be significantly low.

Disposal of Bilge Fluids and Drainage Water

Bilge and drainage waters generated on Drilling rig have the potential to be contaminated with

oily wastes. Drilling rig will be having designated containment and bounding zones where oil products will

be used and stored. While no wastes will be routinely discharged by deck drains, wash down of the decks,

rig floor, pipe rack,, etc., may result in minor quantities of chemical residues (primarily oil and grease)

entering into the marine environment. Drainage water discharges would therefore contain very low levels

of oil and would be readily dispersed after discharge resulting only in some minor localized impact on

marine species. Bilge fluids generated will be treated on-site on Drilling rig in water/oil separator. Effluents

of separated oil will be shipped to onshore periodically in special drums/containers whereas effluent of

separated water will be discharged in sea. Concentration of oil in water discharged will be restricted in

accordance with the International Convention for the Prevention of Pollution from Ships, 1973, as

modified by the Protocol of 1978 (MARPOL 73/78). Meeting requirements for disposal of oil or oily

mixtures at sea, any impact arising from discharge of such treated effluent is therefore considered to be

negligible.

Disposal of Kitchen & Food Wastes

Kitchen & Food waste generated from drilling rig would be macerated (by passing it through

25 mm screen) and discharged directly to water column. Large-scale discharges of organic material can

result in increased biological productivity in the vicinity of the discharge point with a resultant reduction in

dissolved oxygen in receiving waters. Given the limited number of personnel that would be onboard rig

82

(i.e. maximum 100) combined with the anticipated level of dispersion and mixing of wastes in water

column, it is considered that impacts on marine water ecosystem from discharge of such wastes may be

incrementally positive.

Non Routine Discharges

Ballast Water Discharges

The discharge of ballast water from vessels coming into the area can be categorized as a

non-routine discharge and may lead to introduction of exotic species contained in ballast water and

displacement of native species. Discharge of ballast water from Drilling rig and vessels, while in the area

of operations, may also lead to release of low levels of oils and chemicals into marine environment.

Although the probability of ballast water being discharged during the project is considered to be high,

scope of impact will be local with intensity of such impact varying from low to medium. However, it will be

ensured that any discharge of ballast water would be carried out following international maritime guidance

and legal requirements.

5.1.2. Generation & Impacts of Noise

Major noise generating sources during offshore drilling and testing activities will:

Rotary drilling equipment as part of rig;

Diesel engines for power generation;

Mud pumps;

Cranes and material handling equipment;

Supply vessels and helicopter movement

As drilling activity is continuous, part of noise associated with the functioning of rig and ancillaries will

be generated only during drilling hours.

Sound pressure levels associated with drilling are the highest with maximum broadband (10 Hz to 10

kHz) energy of about 190 dB re 1μPa @ 1 m.

Noise Impacts

Project related activities including offshore drilling will lead to considerable local level emission

of noise that may have significant impact on the occupational health of drilling crew and personnel housed

on the drilling rig. Potential impacts on noise quality may arise from air borne noise generated during

drilling operations of rotary drilling equipment, diesel engines for power generation and mud pumps,

leading to perceptible increase in ambient noise levels in immediate vicinities. Noise is also likely to be

83

generated during rig mobilization and also during operation of supply vessels and helicopter. However,

noise so generated will be comparable in level to other drilling related activities and would be continuous

in places (drilling location and ports) and intermittent along transportation routes. The value range of

noise generated from various sources during offshore exploratory drilling operations is as follows:

Helicopter : 103 to 105 dB(A)

Diesel Generators : 60 to 70 dB(A)

Mud Pumps at the Rig : 90 to 100 dB(A)

Upper Decks : 65 to 73 dB(A)

Control Room & Quarters : 50 to 60 dB(A)

In addition, drilling would also result in generation of underwater noise which has the potential

to affect the marine ecology in and around the drill locations. The quantum of noise, its quality and related

impacts and their significance is discussed in the following paragraph.

Atmospheric Noise Emanated from Rig and DG Sets Drilling rig and associated machinery,

including high power DG sets, mud pumps, shakers, etc., will emit very high noise during drilling

operations. Typical noise levels emanated from drilling rig and DG sets are of the order of 95 – 100 db

(A) and 100 -105 db (A) respectively.

Moreover, as drilling is a continuous (24x7) activity, such noise will be emitted during both

daytime and nighttime and may lead to significant impact on drilling crew on rig, unless proper mitigation

measures are implemented. The offshore project block is located in shallow sea but at a considerable

distance from the coastal area, so the above impacts are expected to be localized and have potential

effect only on workers at site.

Noise Emanated from Supply Vessels and Helicopter Movement

Supply vessels and helicopters will be deployed for transportation of resources (water, fuel

and equipment, etc.) and personnel to the drilling rig respectively. This will result in an incremental

increase of noise levels because of additional maritime traffic along the supply routes. However, noise

levels increase will be intermittent having only localized impacts along the corridor of no or low

significance. Also, since there exist predefined shipping routes near to Nhava base, it is expected that

marine animals in this region are accustomed to noise generated from passing vessels. Although vessel

activity along the shipping route between shore and offshore block would increase, it is expected that if

animals initially displayed avoidance behavior, they would eventually return to the affected area once

they become accustomed to the increased noise levels or once noise source had moved or ceased.

Taking into account limited movement of such vessels and helicopters any cumulative noise related

impacts arising from vessel activities are therefore considered to be negligible.

84

In addition, noise impacts are measured in terms of logarithmic equivalent (LeQ) averaged

over hours, considering transient nature of project and intermittent plying of transport vessels and

helicopters (moving sources), no significant impact is envisaged.

5.1.3. Marine Ecological Impacts

Impacts from Physical Presence of Rig

Drilling rig to be utilized for the offshore exploratory project is a Jack-up type of MODU, which

will be stationed at each of the drilling locations. Underwater structures and apparatus like risers will be

sunk from rig to the sea floor to enable drilling operations. It is a well-established fact the such sub-sea

structures can provide new stable areas for marine flora and fauna to colonize. Development of colonies

may in fact be beneficial for the local fish populations. In this event, the structures may attract marine

species to the area as the structures in effect form artificial reefs where fish can seek food, shelter and

protection. Such positive effects have been confirmed by research studies conducted on fish population

near offshore installations. Such studies have revealed that fish growing around the manned and

unmanned installations were found to grow better than those caught at a remote site unaffected by

manmade structures (Mathers et al., 1992b). It was also found that fish caught around the man-made

installations were in good condition with no evidence of lesions or other defects on their skin (Mathers et

al., 1992b).

85

Chapter-6

ENVIRONMENTAL MANAGEMENT PLAN

6.1. MUD MAKE-UP AND MUD & CUTTINGS DISPOSAL:

As has been elucidated earlier that the mud system used in drilling by ONGC is largely inert

in nature and contains no toxicity, the same will be disposed of into the sea only after drying and on being

washed thoroughly as per standard legal guidelines. In addition, WBM mud system will be used following

the 2005 guidelines/ notification of MoEF and accordingly, the rate of discharge of discharge of the drill

cuttings into the sea will be <= 50 bbls per hour

Mitigation measures for discharge of mud cuttings will include the following:

Strict compliance with regulatory provisions relating selection of drilling fluid chemicals,

separation of drilling fluid from cuttings and proper washing of drill cuttings;

Design of disposal mechanism to ensure sufficient dispersal of discharged cuttings, thereby

causing minimal impacts on marine water productivity; and

Monitor effective functioning of outfall equipment during operations.

6.2. MEMBERSHIP OF COMMON DISPOSAL FACILITIES:

The solid waste generated on the rig will be segregated and stored in colour coded bags. The

solid waste will be transported back using support vessels or with the rig, to the Nhava supply base of

ONGC. At Nhava supply base the segregated waste will be treated separately. Hazardous waste, if any,

will be sent to authorized hazardous waste recyclers and disposal facility.

6.3. MEASURES TO HANDLE OILY WASTE DISCHARGES

Bilge and drainage waters generated on the rig may have the potential to be contaminated

with oily wastes. Drilling rig will be having designated containment and bunding zones where oil products

will be used and stored. While no wastes will be routinely discharged by deck drains, wash down of the

decks, rig floor, pipe rack, etc., may result in minor quantities of chemical residues (primarily oil and

grease) entering into the marine environment. Drainage water discharges would therefore contain very

low levels of oil and would be readily dispersed after discharge resulting only in some nominal localized

impact on marine species.

Bilge fluids generated will be treated on-site on the rig, in water/oil separator. Effluents of

separated oil will be shipped to onshore periodically in special drums/containers with effluent of separated

86

water being discharged in sea. Concentration of oil in water discharged will be restricted to less than 15

ppm in accordance with the International Convention for the Prevention of Pollution from Ships, 1973, as

modified by the Protocol of 1978 (MARPOL 73/78). Impact due to disposal of oil or oily mixtures at sea,

arising from discharge of such treated effluent is therefore considered to be negligible.

Mitigation Measures

Typical mitigation measures include:

Use of well-maintained oil/water separator;

Operational controls covering materials storage, wash-downs and drainage systems;

Maintaining a high level of housekeeping on board;

Use of only low toxicity chemicals on board; and

Design an adequate storm water drainage system to allow oily waste and contaminated

liquid waste, if any, to be collected and contained separately from clean storm water

6.4. SEWAGE TREATMENT AND DISPOSAL

Black Water also known as sewage will be generated from toilets on the rig and will primarily

include faecal material and urine. Rig operations will typically result in the generation of 9 m³ of sewage

per day. Once collected through headers, they will be passed through a sewage treatment plant (STP).

The wastes will then be passed through a screen of less than 25 mm diameter and an extended aeration

system prior to their discharge into the marine environment. In this case also, sewerage treatment on-

site will be done in compliance with MARPOL 73/78 requirements.

6.5. SOLID WASTE HANDLING

Combustible and non-combustible wastes routinely generated at offshore facilities will be

segregated at source and shipped to shore for re-use, recycling, or disposal. Efforts will be made to

eliminate, reduce, or recycle wastes at all times.

A waste stream inventory for the proposed offshore exploratory drilling project will be compiled

to identify predicted wastes for the spectrum of activities throughout the lifetime of the project. Overall,

the project waste management strategy will be adopting an effective solid waste treatment hierarchy.

However, the ultimate responsibility for effective waste disposal lies firmly with ONGC, who will ensure

that the project contractor(s) have adequate training and follow stipulated waste management procedures

for minimizing, handling and storing waste; that meet acceptable standards; and audits are carried out to

ensure these are achieved. Detailed waste management procedures will be put in place and all personnel

employed at on the rig will receive formal waste management awareness training, particularly regarding

the proper waste segregation, storage and labeling procedures and potential recycling of waste.

87

6.6. SPENT OIL HANDLING

Spent oil collected during the various activities of the offshore drilling on drilling rig will be

collected and stored separately in the labeled containers. These containers will then be sent to onshore

Nhava supply base from where it will be finally sent to the authorized hazardous treatment facility.

6.7. OIL HANDLING FROM WELL TEST OPERATIONS

Once drilling operations are completed and if sufficient indications of hydrocarbons are

noticed while drilling, the well may be tested by perforations. It is estimated that well testing period would

be about 1-2 days per well. Well testing will be carried out in accordance with Well Testing Program to

safely meet program objectives. During well testing oil will be stored in storage tanks, gas will be flared

up. Oil will be transported to base facility.

6.8. NOISE ABATEMENT MEASURES

The following mitigation measures will be adopted for noise reduction during the proposed offshore exploratory

drilling

Install sufficient engineering control on machineries (like mufflers, enclosures,, etc.,.) to

reduce noise and vibration emission levels at source;

Ensure that staff mobilized for the project is trained to use Personnel Protective Equipment

(PPE) like ear plugs/muffs and aware of noise related safeguards at workplace;

Identify areas sensitive for marine life such as feeding, breeding, calving, and spawning

areas in close proximity to the drill locations;

Undertake planning of navigational route for the drilling rig and supply vessels to avoid

Potential Fishing Zones and sensitive habitats in Arabian Sea;

Undertake proper preventive maintenance of supply vessels, helicopters and DG sets to

reduce noise levels;

Monitor presence of any sensitive species in the study area prior to the onset of any

exploratory activity;

Maintain relatively safe speed for vessels transporting equipment and fuel to the project site

in Arabian Sea;

6.9. MEASURES TO MINIMIZE DISTURBANCE DUE TO LIGHT AND VISUAL INTRUSIONS

The physical presence of the drilling rig is also to be felt at night because of the illumination

at night by deck and navigational lights. Other possible sources of illumination will be flaring conducted

for a short period of time during well testing phase. Artificial lighting and well testing flares may result in

the attraction of marine species leading to their disorientation and confusion behaviour. However, such

88

behaviour is particularly observed in hatchelling turtles, female turtles and sea birds. Lights on the rig

may also result in the sea birds concentrating on the immediate vicinity of the rig; however the operation

is short term in nature and is not likely to have a significant impact. As physical presence at drilling location

is intrinsically linked with the proposed drilling activities, and the fact that the adverse environmental

impacts are minimal, no mitigation measures are proposed to further reduce the impacts. However, a

reconnaissance survey will be carried out before the finalization of the drill locations to ensure that the

area is not the point of convergence or gathering for any sensitive marine species.

89

Chapter 7

ANALYSIS OF ALTERNATIVES (TECHNOLOGY & SITE)

ONGC as an integrated oil and gas Corporate has developed in-house capability in all aspects

of exploration business i.e., Acquisition, Processing & Interpretation (API) of Seismic data, drilling, work-

over and well stimulation operations, engineering, construction, production, processing, refining,

transportation, marketing, applied R&D and training, etc. Wherever possible alternatives with respect to

rig, mud, on-site support base, and drilling locations are considered and best possible option is selected.

7.1. DRILLING LOCATIONS

The main objective of the exploratory drilling in block MB-OSN-2005/3 is to identify the block

area that contains oil and/or gas. The prospective drilling areas for the block is selected on the basis of

the 3D seismic survey. Based on the interpretation of 3D seismic data (acquisition ensued), specific

drilling locations are finalized. Before finalization of drilling locations information on the stability of surface

sediments and potential subsurface hazards (e.g. shallow gas formations) are gathered to ensure the rig

not to encounter problems when positioning or drilling the surface hole.

MoEF, through its ToR for this block, has asked ONGC for commitment on no drilling within

1 km from coastline. The exploratory drilling locations in the block MB-OSN-2005/3 is over 250 km from

the coast, thus MoEF requirement/ stipulations are met with spontaneously.

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Chapter 8

ENVIRONMENTAL MONITORING PROGRAM

Monitoring is one of the most important components of a management system. ONGC’s IMS

(Information Management System) requires continuous monitoring to be carried out for environmental,

safety and health impacts and the performance of EMP implementation, etc. Monitoring indicators have

been developed for each of the activities considering the mitigation measures proposed. Real time

measurements of these indicators will be carried out during drilling and data will be submitted to MoEF

as per statutory requirements of MoEF.

ONGC is required to record daily discharge of drill cuttings & drilling fluids in sea and also to

monitor the effluent quality. Compliance report will be prepared and it will be submitted to MoEF on 6

monthly basis or as per the conditions specified by MoEF.

Monitoring results would be documented, analyzed and reported internally to Offshore Drilling

Supervisor, Wells Operations Manager and HSE Coordinator. Monitoring requirements have been

described in the following Table 8.1. Frequency of monitoring and responsibility of carrying out the

monitoring have also been presented in the table.

TABLE 8.1: ENVIRONMENTAL MONITORING PROGRAM

Sr.

No. Particular Criteria/Regulation

Parameter to be

monitored

Frequency

of

Monitoring

Responsibility

1

Lo

cati

on

of

dri

llin

g w

ells

ONGC shall be drilling the

exploratory wells much

beyond 5 km from the coast

(nearest being 42 km SSW,

thus meeting the MoEF

requirement.

Drilling locations Once before

start of

drilling

activity.

Drilling HSE

Team

2

Qu

alit

y o

f se

a w

ater

Physico-chemical

characteristics of marine

surface water

Physical parameter – pH,

Salinity, temperature,

Chemical parameter – Oil

& Grease, Total

Petroleum, Hydrocarbons

(TPH), Petroleum

Aromatic Hydrocarbons

(PAHs)

Once in 24

hrs.

if no toxicity is

found, then

once in a

week.

Drilling HSE

Team

91

3

Use

of

mu

d ONGC is committed to using

of only Water Based Mud

(WBM) for the offshore

exploratory drilling

operations.

Quantity & characteristics

of mud to be used

Toxicity as per CPCB

guidelines.

Once every

year

Drilling HSE

Team

4

Wat

er

Usa

ge

Commitment to use an

average of 40 m3/day of

water during the drilling

period

Monitor the quantity of

water being used in

vessel

Drilling HSE

team

5

No

ise

Gen

erat

ion

Noise levels to which drilling

crew is exposed

Noise monitoring at rig Weekly, as

per CPCB

guidelines

Drilling HSE

team

6

Dri

llin

g

Mu

d a

nd

Cu

ttin

gs

Drilling Mud

Quantity & Characteristics Once for

each well as

per CPCB

guidelines

Drilling HSE

team

Drill cuttings Quantity

7

Eff

luen

ts

Drilling Effluents

Residual chlorine (Cl2)

after treatment

Weekly, as

per CPCB

guidelines

Deck drainage

Sanitary wastes- volume &

regular quality

as per MARPOL

8.1. DETAILED BUDGET AND PROCUREMENT SCHEDULES OF ENVIRONMENTAL MONITORING

ONGC has regular procurement plans for various operations related to hiring of drilling rig

services and associated facilities. These also include various aspects related to environmental

management measures. Thus procurements related to EMP are inbuilt in the procurement requirement

of ONGC.

Various man power requirements are provided by Drilling HSE, Basin HSE and Corporate

HSE teams of ONGC.

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Chapter 9

ADDITIONAL STUDIES

9.1 RISK ASSESSMENT

ONGC plans to drill one exploratory well and the exploratory drilling will be taken up in the

Block MB-OSN-2005/3 having an area of 1685 km2, and bathymetry ranging from ~90 to ~100 m, during

this phase of exploration.

Drilling will be performed using a self-contained Mobile Offshore Drilling Unit (MODU), a Jack-

up / Floater rig capable of performing shallow water drilling. Well testing will be conducted in the event of

discovery of hydrocarbon at such formation to establish hydrocarbon potential in terms of flow rates and

reservoir pressure. Following drilling and well testing activities, wells will be permanently abandoned or

sealed off for further development. Once well has been secured and all necessary equipment has been

retrieved, MODU will be mobilized to the next drill location.

The Risk Assessment encompasses identification of risks involved in the drilling process and

the associated activities in the drilling program, and assessment of probability of certain consequences.

9.1.1. Stages for which risk assessments are undertaken

Exploration drilling activity can be broken up into a series of stages during which different risk

assessments are undertaken:

Pre-operational assessments and regulatory approvals

Well design

Selection of rig, equipment and services

Pre-mobilization, mobilization

Drilling

De-mobilization

The Risk Assessment ascribed here has been undertaken prior to commencing of drilling

operation, and as part of the regulatory requirements, involving evaluation and disclosure of major risks

to the members of the Expert Appraisal Committee (EAC) of MoEF and other regulators, and

demonstrates that the exploratory wells, in principle, can be drilled in a manner not resulting in harm to

individuals or damage to the environment.

93

This assessment relies on environmental and social sensitivities associated in the region,

data on past accidents in the oil and gas industry, information on past E&P activities undertaken by ONGC

in general and specifically in this area / region, and HSE management systems of ONGC. This study

however has certain limitations for the absence of sufficient details of the Drilling Rig or associated

support systems to be deployed for the proposed exploratory drilling program.

This report on Quantitative Risk Assessment (QRA) aims at providing a systematic and

syntactic analysis of the major risks that could arise as a result of offshore exploration activities of ONGC

in the MB-OSN-2005/3 block.

The QRA process outlines rationale behind the identified risks based on their significance and

also provides for appropriate preventive and risk mitigation measures. It is anticipated that the results of

the QRA would provide valuable inputs for the overall project planning, ONGC’s existing IMS and the

DSS (Decision Support System) for effectively addressing the identified risk to ensure that the project

risks stay at ‘As Low As Reasonably Practicable (ALARP)’ levels at all times during project

implementation. In addition, the QRA will also help in assessing risks arising from potential emergency

situations like a large oil spill and develop a structured Emergency Response Plan (ERP) to restrict

damage to personnel, infrastructure and the environment.

The risk study for the offshore project has considered all aspects of operation of the MODU

and other associated activities during the exploratory phase. Oil spills, loss of well control / blow-out,

vessel collisions, process leaks and helicopter crashes constitute the major potential hazards that may

be associated with the project. External and environmental risk factors (e.g., collisions with passing

merchant vessels, severe weather and seismic events) were considered in the assessment. However,

the risks or hazards associated with development and production program of exploratory wells has been

precluded for it being beyond the scope of the study.

The following section describes the methodology of the risk assessment study and then

presents the assessment for each of the potential risk separately.

9.1.1.1 Objective of QRA

The overall objective of the QRA is to identify the main contributors of major risks arising from

the offshore project which in turn will help in understanding the nature of hazards, evaluate and prioritize

them keeping in mind the ALARP principle and then suggest practicable targets for risk reduction, if any.

The specific objectives of this risk assessment are to:

Identify potential risk scenarios that may arise from operation of supply ships, helicopter

transport, etc.

94

Analyze the possible likelihood and frequency of such risk scenarios by reviewing historical

accident data.

Predict the consequences of such potential risk scenarios and if consequences are high,

establish the same by through application of quantitative simulations.

Recommend feasible preventive and mitigation measures as well as provide inputs for

drawing up an Emergency Response Plan (ERP) for the project.

The objectives of the QRA meet the criteria set for risk assessment for offshore operations in the

Petroleum and Natural Gas (Safety in Offshore Operations) Rules, 2008.

9.1.1.2 Risk Assessment Methodology

Risk associated with offshore oil and gas activities has two main elements - the risk of an

event happening - an oil spill, and the probability that that it will impact a receptor, such as an ecologically

sensitive area. For the purposes of this assessment, a risk ranking methodology based on likelihood and

consequence has been developed in line with specific criteria defined by ONGC for this project, and

represented in the form of a risk matrix.

The risk matrix is a widely accepted and standardized method of semi-quantitative risk

assessment and is preferred over purely quantitative methods, given its inherent limitations to define a

risk event with certainty. The application of this tool has resulted in the prioritization of the potential risk

events for the proposed drilling operations thus providing the basis for drawing up risk mitigation

measures leading to formulation of plans for risk and emergency management. The overall approach is

summarized in the Figure 9.1

FIGURE 9.1: RISK ASSESSMENT METHODOLOGY

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9.1.1.3 Hazard Identification

Hazard identification for the purposes of the QRA comprised of a review of the project and

associated activity related information provided by ONGC. In addition, guidance provided by knowledge

platforms/portals of the upstream oil & gas industry including OGP, ITOPF and DNV as well as historical

information available with ONGC were used to identify the potential hazards that may arise out the

proposed project activities.

Primarily, six major categories of hazards that can be associated with the project have been dealt with

in detail. They are as follows:

Oil Spills

Blowouts

Collisions

Helicopter crash

Process leaks

Process and non-process fires / explosions

Other possible hazard scenarios like chemical spills, falls, etc. has not been considered for

detailed assessment as preliminary evaluation has indicated that the overall risk that may arise out of

them is or negligible. In addition, it is understood that the causative factors and mitigation measures for

such events can be adequately taken care of through existing safety management procedures and

practices of ONGC.

It must also be kept in mind while evaluating the QRA that many of the hazards identified are

sometimes interrelated with one hazard, often has the ability to trigger off another hazard through a

domino effect. For example, a large oil spill in most instances is caused by another hazardous incident

like a blowout, a process leak or a collision. This aspect has been considered while drawing up hazard

mitigation measures and such linkages (among hazards) has also been given due Importance for

managing hazards and associated risks in a composite manner through ONGC safety management

system and the Emergency Response Plan.

9.1.1.4 Frequency Analysis

The analysis of frequencies of occurrences for the key hazards is important to assess the

likelihood of hazards during the lifecycle of the project. With relevance to the risk assessment study of

the proposed offshore exploratory project, major information sources viz. statistical data, historical

records and global offshore industry experience were considered for the frequency analysis of the major

identified risks.

The following accident databases and published oil industry databases have been consulted for arriving

at probable frequencies of identified hazards for the purpose of this QRA:

96

The Worldwide Offshore Accident Databank (WOAD) – world’s most extensive database of

offshore accidents and incidents maintained by DNV;

SINTEF Offshore Blowout Database - a compilation sponsored by 6 operators and 2

consultants;

CAA Helicopter Data – statistics published by the UK Civil Aviation

Accident Data published by DNV Technica

Environmental & Safety Performance of E & P Industry published by oil & gas producers

OGP;

Oil Spill Statistics published by International Tankers Owners Pollution Federation (ITOPF)

Likelihood Ranking Criteria Definition

E Higher than 1 occurrences/year

D Between 10-1 to 1 occurrences/year

C Between 10-4 to 10-3 occurrences/year

B 10-3 to 10-1 occurrences/year

A Between 10-6 to 10-4 occurrences/year

0 0 Lower than 10-6 occurrences/year

9.1.1.5 Consequence Analysis

In line with the frequency analysis, hazard prediction / consequence analysis exercise has

been done to assess the resulting effects in the event of an accident and their likely impact on project

personnel, infrastructure and environment. The consequences of accidental events on the marine and

social environment have been studied to evaluate any major impact to the aforesaid environment. Overall,

the consequence analysis takes into account the following aspects:

Magnitude of impacts in terms of area involved

Stakeholder concern

Impact on ecology/biodiversity

Time period for natural recovery and cleanup in case a risk scenario unfolding

The following criteria for consequence rankings have been drawn up in context of the possible

environmental consequences in the event of the risk events unfolding during the drilling operations:

97

TABLE 9.1: SEVERITY CATEGORIES AND CRITERIA

Environment Severity

Ranking Criteria Definition

Major International Impact

5

International stakeholder concern

Impact on licenses / acquisitions

More than 5 years for natural recovery

More than 5 months for clean-up Reduction of

biodiversity

Impact on special conservation areas.

Involved area > 100 km2 – Spill= 5000 MT

Major National Impact 4

National stakeholder concern

Impact on licenses

2-5 years for natural recovery

Up to 5 months for clean-up

Threatening to biodiversity

Impact on interesting areas for science.

Involved area < 100 km2 – Spill= 700 MT

Local Impact 3

Regional stakeholder concern

1-2 years for natural recovery

1 week for clean-up

Threatening to some species

Impact on protected natural areas.

Involved area < 10 km2 - Spill = 100 MT

Minor Impact 2

Some local stakeholder concern

1 year for natural recovery

Impact on small no of not compromised species.

impact on localized ground

Involved area < 1 km2

Spill = 10 MT

Slight Impact 1

No stakeholder impact

Temporary impact on the area.

Involved area < 0.1 km2

Spill < 1 MT – no sensitive impact on ground

9.1.1.6 Risk Evaluation

Based on ranking of likelihood and frequencies, each identified hazard has been evaluated

based on the likelihood of occurrence and the magnitude of consequences. The significance of the risk

98

is expressed as the product of likelihood and the consequence of the risk event, expressed as

“Significance = Likelihood X Consequence”.

The figure below Illustrates all possible product results for the four likelihood and

consequence categories and the Fig. 9.2 and Fig. 9.3 assign risk significance criteria in three regions that

identify the limit of risk acceptability according to the policy and the strategic objectives. 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.

FIGURE 9.2: RISK MATRIX & ACCEPTABILITY CRITERIA

Likelihood of Occurrence

Sev

erity

of C

onse

quen

ce

O A B C D E

1 Continuous Improvement

2 Risk Reduction

Measures

3

4 Intolerable Risk

5

FIGURE 9-3: RISK CATEGORIES AND SIGNIFICANCE 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.

9.1.2. Key Risks involved

The key accidental scenarios corroborating safety and environmental risks due to offshore exploratory

drilling program in the current region are:

Fire and Explosion due to Blowouts and other reasons

Accidents during sea transport of materials and supplies

Accidents during air transport of personnel

Oil Spills

Risk and consequence of oil spills are included in separate section, while blowouts and other risks

relating to air and sea side transport accidents are included in the following sub sections.

99

9.1.2.1 Blowouts

A blowout in a hydrocarbon exploration activity can be defined as any uncontrolled flow of

formation fluids from the reservoir to the surface, due to formation pressure exceeding the hydrostatic

pressure of the mud or fluid column and failure of blowout prevention measures. For an offshore drilling

activity, blowout events may occur at the drill ship level or subsea and may result in pool /jet fires, vapour

cloud explosions or sometimes may lead to release of toxic gases like Hydrogen Sulphide.

Blowouts during offshore operations may be initiated during both drilling and development

phase and also as a result of external causes viz. earthquakes, ship collision, and structural collapse. In

the context of the proposed project, offshore operations will be limited to exploratory drilling and testing.

Therefore, any incidence of blowout during the aforesaid phases may occur as a result of loss of well

control due to formation fluid entry into well bore, well head damage or loss of containment. The

underlying causes of most of the blowout incidents (excluding external causes) occurring worldwide can

be interpreted as organizational and managerial. An analysis of blowout causes into such factors

attempted for the Marintek database (NSFI 1985) revealed that the main causal factors were improper

maintenance, operational failures and inadequate supervision.

Blow Out Frequency Analysis

Blowout frequency estimates are obtained from a combination of incident experience and

associated exposure in a given area over a given time period. Due to limited offshore oil & gas related

activities in the offshore region, blowouts that have occurred at other offshore locations worldwide have

been considered for the blowout frequency analysis. Input data for the frequency analysis of blowout

events were taken from DNV’s database, viz., WOAD (World Offshore Accident Database). Review of

blowout frequencies from the database reveals a frequency 1.1 X 10-2 per operation per year for drill

ships (comparable to the MODU to be deployed for the drilling activity) compared to Jack Up Rigs (9.8 X

10-3), and Fixed Platforms (9.3 X 10-4).

Since the proposed project involves only exploratory drilling, measurement of exposure for

blowout incidents has been determined by considering blowout frequencies during drilling and by the

platform type. The blowout frequency for the proposed 6 wells have been obtained by multiplying the

blowout frequencies per well year by the no of wells drilled, and the time taken for drilling each well.

Estimated frequency for blowout for the proposed drilling operation in exploratory block MB-

OSN-2005/3 is: Probability for blowout from ONGC drilling operations = 1.1 X 10-2 (prob/ year / drilling

operation) X 1(no of drills) X 0.2 (time taken for each drill in yrs) = 0.2 X10-2

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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 oil resulting in a slick or spill on the sea

release of drilling fluids and resulting spill leading to contamination of marine environment

release of toxic / flammable gas which may have deleterious/detrimental effect on the drill

ship personnel

ignition of the flammable gas / oil released resulting in a jet of fire, pool of fire or an explosion

Ignition of released oil and gas can possibly result in considerable harm. With historical data,

40% of blowout incidences to have led to significant damage to the drill ship / platform (WOAD database)

and resulted in associated fatalities amongst drilling crew and support personnel present on the ship /

platform. Also, ignition has been recorded world over, on an average, in about 30% of the blowout cases

(SINTEF offshore blowout database). However, on the positive side, with improvement of offshore drilling

technology, number of offshore blowouts occurrences has significantly gone down in the last decade.

A public domain database maintained by DNV for all offshore hazards including 312 blowouts worldwide

from 1970-96.

Risk Ranking for Blowouts

Likelihood Ranking - C

Consequence Ranking - 4

Risk Ranking - 4C (High)

Preventive and Mitigation Measures

Blowouts being events which may be catastrophic to any well operation, it is essential to take

up as much a preventive measures as feasible. Following measures would be implemented:

Necessary active barriers (e.g. Blowout Preventer) will be installed to control or contain a

potential blowout.

Close monitoring of drilling activity would be done to check for signs of increasing pressure,

viz., shallow gas formations.

Adequate precautionary measures to be taken in case of a natural event like earthquake or

a cyclone.

101

9.1.2.2 Collisions Involving MODU (Jack-up Drilling Rig)

A collision event is considered for the risk assessment for the impacts on MODU by other drill

ships or other marine vessels working nearby or passing by it. The following possibilities have been taken

into consideration:

support vessels which approach the MODU under their own power including supply vessels,

standby vessels, etc.

Collisions may vary from minor bumps to rare but highly damaging full-speed collisions. The

frequency for such incidences is strongly dependent on the severity of the collisions

included. The types of collisions possible in this are as follows:

On arrival – where the visiting vessel fails to stop when it reached the platform;

Manoeuvering – where the vessel misjudges a turning or approach manoeuver, and the hits

the MODU at a relatively low speed

Drifting – where the vessel loose power or suffers a failure of dynamic positioning and drifts

into the platform because of winds or waves.

The collision frequency would be expected to vary roughly in proportion to the number of

visits, particularly for supply vessels, which are again of a similar pattern. The frequency of collisions will

also depend on the weather conditions prevailing in the offshore region near the coast during the drilling

period, especially for minor collisions. As exact vessel movement data for the ONGC India operations

are not available at this time, an average vessel movement (Technica, 1987) of about 3.6 vessels / week

has been assumed.

Assuming the number of visits to the MODU as 5.0 vessels per week, the typical overall

frequency of moderate to severe collision by a support vessel with the MODU can be taken as 1.0X10-4

per visit. Estimated frequency for support vessel collision for the proposed drilling operation in exploratory

block MB-OSN-2005/3 is:

Total number of visits = 5 / 7 X 210 = 150

Frequency for collision = 1.0 X 10-4 X 150 = 1.5 X 10-2

Collisions Involving MODU and Passing Vessels

Collisions with offshore oil structures involving passing vessels are generally very rare (about

5 % of all reported collisions) but can be potentially very damaging. Probabilities for passing vessel

collisions can be estimated from historical experience. However, the frequencies are uncertain and

statistically insufficient as only few passing vessel collisions have has been reported. Historical data have

limited value because they are often unable to reflect local traffic levels with reasonable degree of

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accuracy and also because the sea has few formally defined shipping lanes and ships tend to follow

informal lanes voluntarily between ports.

Collisions Involving Supply and Other Vessels

There is a negligible probability of supply vessels colliding with other commercial vessels on

route to the MODU while maneuvering near to the Nhava base. These collisions may happen because

of navigational difficulties or because of prevailing traffic density near JNPT. However, the traffic on local

routes is highly regulated and controlled. So the possibility of such collisions happening is considered to

be minimal.

Consequences and Effects

The analysis of collision consequences is generally based on the principle of conservation of

energy. The incident kinetic energy of a vessel on a collision course can be transferred to the MODU

during the impact. The magnitude of energy transfer will depend on the mass of the vessel and on the

square of its speed at the time of impact. However, in the case the collision is as a result of a glancing

blow from a support vessel, where the vessel brushes against the platform, the kinetic energy transfer is

minimal and is expected to cause minimal damage to the MODU. The impact of a full-on collision may

however be more severe and may lead to structural damage to the MODU. The risk to personnel manning

a platform / drill ship from a collision in terms of fatalities or injuries has been historically found to be very

low, if not resulting in a catastrophic incidence like a blowout. It should be noted that the MODU would

be connected to the drilling apparatus at the sea bottom; a collision involving high energy transfer 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


Risk Ranking - 3C (Medium)


A Vessel Management Plan will be formulated and implemented to reduce collision risk, both vessel–

vessel and MODU–vessel and will address the following:

Mandatory 500 m safety zone around platform;

Operational restrictions on visiting vessels in bad weather;

Defined vessel no-go areas within safety zone; and

Agreed approach procedures to platform by supply and safety vessels.

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9.1.2.3 Helicopter Crashes

The journey to and from offshore installations has historically been one of the main reasons

for accidental death or injury to many offshore workers. For the ONGC India drilling activities, crew

transport to and from the MODU will be taken care of by helicopter for its speed, convenience and good

operability under rough weather conditions.

Frequency Probability

Several approaches exist to analyze probability of helicopter crash risks. The most common

approach involves the use an overall Fatal Accident Rate (FAR) value (e.g. SINTEF 1990). However,

there are certain inherent deficiencies in adopting this approach in spite of the fact that it provides

convenient risk numbers. 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.

Taking this approach and considering historical data from the UK sector which is available, while

accounting for both the flying time and number of flying stages involved, the Individual Risk per journey

can be calculated as Individual Risk (IR) per journey = 1.7 X 10-6 X flying time (hours) + 2.7 X 10-7 X No.

of stages per journey.

Consequences and Effects

Helicopter crashes with offshore oil & gas exploration and production have happened routinely

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 - BC


Risk Ranking - 3B (Medium)


Following preventive and mitigation measures will be adopted with respect of helicopter operations:

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

by ONGC India.

ONGC India should ensure that the pilot/pilots who will be operating have got appropriate

training on similar craft.

Effective arrangements for coordination would be developed with air traffic control room at

Nhava base, as also in the MODU;

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

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.

9.1.3. Risk Mitigation Measures

9.1.3.1 Well Planning & Design

Exploration wells are designed to manage the uncertainty in the true nature of the well to be

drilled. The possibility of shallow gas, uncertainty in pore-pressure and temperature, porous and

permeable intervals, weak formations, etc. all need to be assessed, and the well design and drilling

program developed to cater for ‘worse-case’ scenarios. Offset well data, computation modeling and site

specific survey data allow the geoscientists to provide the drilling engineers with information on the likely

range (probabilistic) and maximum values of key design parameters. The drilling engineer designs the

well (and the associated drilling programme) on the basis of maximum anticipated values.

Explicit risk assessment, in terms of assigning quantitative probabilities of failure to all parts

of the well design, does not feature in the design of a typical exploration well. However, risk assessment

is implicit within the design process, specifically through the adoption of operational manuals and

procedures and industry recognized design approaches by ONGC.

ONGC and other private E&P operators such as RIL have in the past undertaken drilling

activities in the offshore region around the coast of Maharashtra. This has led to a fair amount of

geological information and offset well data from the region, based on which ONGC will be able to plan

and design exploratory wells in the block, with minimal uncertainties and therefore higher probability of

avoiding accidental scenarios such as blowouts.

As per ONGC’s Management Systems of Offshore Drilling and HSE, and in compliance with

Petroleum and Natural Gas (Safety in Offshore Operations) Rules 2008, ONGC will ensure that:

A Well programme describing the individual activities and the equipment to be used will be

prepared prior to starting well activities

The management system with associated processes, resources and operational

organization will be established;

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Steering documents, including technical documents for drilling and well testing operations,

will be made available, in an updated version and the operational personnel shall be

acquainted with it.

Commissioning process prior to startup of facilities for first time or after technical

modifications will be completed

Well barriers:

During drilling and other related well activities, there will at all times be at least two

independent and tested well barriers after surface casing a in place. Well barriers will

be designed in such a manner that unintentional influx, cross flow to deformation

layers and outflow to the external environment is prevented.

Well barriers will be designed in such a manner that their performance can be verified.

If a barrier fails, during drilling and other related well activities, no other activities will

be undertaken in the well than those to restore the barrier.

When a well is abandoned, the barriers would be designed to provide integrity for the

longest period of time in such a manner, inter alia, that outflow from the well or

leakages to the external environment do not occur.

ONGC will choose well location and well path on the basis of well parameters of

importance, including occurrence of shallow gas, other hydrocarbon bearing

formation layers and distances to adjacent wells and to ensure that it is possible to

drill a relief well from two alternative locations. The well path will be known at all times.

ONGC will ensure that the necessary actions are planned including setting of casing above

all known shallow gas hazard zones to handle occurrence of situations of shallow gas or

other formation fluids.

During drilling and well activities, drilling and well data will be collected and monitored to

verify the well prognoses, in order that necessary actions may be taken and the well

programme may be adjusted, if necessary.

Well control:

Well control equipment will be designed, installed, maintained, tested and used so as

to provide for well control.

In the case of drilling of top hole sections with riser or conductor, equipment with

capacity to conduct shallow gas and formation fluid away from the facility, until the

personnel has been evacuated, will be installed.

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Floating facilities shall have an alternative activation system for handling critical

functions on the blow out preventer.

Accumulator for surface and subsurface well control equipment will have minimum

useable fluid capacity as per industry standards in order to perform closing and

opening sequences as applicable to secure the well.

The pressure control equipment used in well interventions will have remote control

valves with locking devices.

The well intervention equipment will have a remote control blind or shear ram as close

to the Christmas tree as possible

If well control is lost, ONGC will ensure that it shall be possible to regain the well

control by direct intervention or by drilling a relief well.

ONGC will prepare an action plan describing how the lost well control can be regained

ONGC will set operational limitations in relation to controlled well flow

Securing of wells before abandoning

All wells will be secured before they are abandoned in such a manner that well

integrity remains intact for the period abandoned.

With regard to subsea completed wells, the well integrity will be ensured if the wells

are planned to be temporarily abandoned

Radioactive sources will not be left behind in the well.

In case it is not possible to retrieve the radioactive sources and these have to be left

in the well, ONGC will follow proper abandonment procedure as per guidelines of the

Department of Atomic Energy, Government of India.

Compensator and disconnection systems:

Design of compensator systems will be based on robust technical solutions so that

failures do not lead to unsafe conditions.

Floating facilities shall be equipped with a disconnection system that secures the well

and releases the riser before a critical angle occurs

Drilling fluid system:

The drilling fluid system will be designed in such a manner that it will mix, store,

circulate and clean a sufficient volume of drilling fluid with the necessary properties

to ensure the drilling fluid’s drilling and barrier functions.

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The high pressure part of the drilling fluid system with associated systems will in

addition have capacity and working pressure to be able to control the well pressure

at all times.

Availability of sufficient quantity of drilling fluid weighting material to subdue the well

at any time during the drilling operation will be ensured

Cementing unit:

The cementing unit will be designed in such a manner that it will mix, store and deliver

as exact volume as possible of cement with the necessary properties to ensure full

satisfactory anchoring and barrier integrity

The unit will be designed in such a manner that remains of unmixed chemicals as

well as ready-mixed cement is handled in accordance with the applicable

environment regulations.

If the cementing unit with associated systems is intended to function as backup for

the drilling fluid system, it shall have capacity and working pressure to be able to

control the well pressure at all times.

Casings and anchoring will be such that the well integrity is ensured and the barrier functions

are provided for the life time of the well.

Equipment for completion and controlled well flow

Equipment for completion will provide for controlled influx, well intervention, backup

well barrier elements and plug back activities.

Completion strings will be equipped with necessary down hole equipment including

safety valves

During controlled well flow, the surface and down hole equipment will be adapted to

the well parameters.

Equipment for burning of the well stream will be designed and dimensioned in such

a manner that combustion residues shall not cause pollution of the marine

environment

ONGC will ensure that controlling well pressure through the work string and the well

flow through the choke manifold at any time

9.1.3.2 Selection of Equipment, Systems and People

Assessing the Ability of the Drilling Rig to Perform the Required Operation

The water depth, environmental conditions, reservoir and geophysical properties will dictate

the type of rig and equipment required to perform the drilling operation. Highly technical risk assessments

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will be undertaken both to demonstrate that the rig is capable of providing an acceptable working

environment, and to determine the limits to which certain operations will be undertaken.

During this phase, the ability of the equipment and systems on the rig to provide a suitable

barrier(s) to well control incidents will be reviewed (e.g., pressure rating and functionality of the BOP).

The ability of a drilling rig to operate at the specific location will be assessed, usually through the

application of an industry recognized site assessment practice. (e.g., Site Specific Assessment of Mobile

Jack-Up Units). The objective being to ensure that the risk of (for example) a structural or mooring failure

does not exceed ONGC’s and the regulator’s risk acceptance requirements.

The risk assessment process is, to an extent, embodied within the relevant design and

assessment standards applicable to the particular type of drilling rig. However, detailed, site-specific risk

assessments support the application of these standards, for example the analysis of borehole data to

establish the risk of a punch-through. Where a drilling rig is deemed to be operating close to the limits of

its operating envelope, more detailed risk assessments may be warranted.

The requirements of the following applicable standards for the listed equipment shall be met

to demonstrate that drilling systems are in compliance with requirements of the Petroleum and Natural

Gas (Safety in Offshore Operations) Rules, 2008 and Drilling Rig (MODU) is thus fit for purpose:

Fire and explosion risk assessment on MODU includes hazards from the wells and well testing

operations. Following fire and explosion hazards related to wells are generally considered:

Subsea shallow gas blow out

Shallow gas blow out in cellar deck

Blow out at drill floor

Subsea blowout

HC gas release / ignition in mud processing area

Fire and explosion in well testing areas

Well programs needs to be designed taking into consideration the anticipated hazards as

listed above. MODUs should conform to conventions and codes of International Maritime Organization

(IMO). Fire and explosion risk management at MODU can be ensured by meeting the requirements of

these codes. Following issues have been taken into consideration by MODU code:

Structural fire protection layout plan for decks and bulkheads

Protection of accommodation spaces, service spaces and control stations

Means of escape

Fire pumps, fire mains, hydrants and hoses

Fire extinguishing systems in machinery spaces and in spaces containing fired processes

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Portable fire extinguishers in accommodation, service and working spaces

Arrangements in machinery and working spaces

Fire detection and alarm system

Gas detection and alarm system

Fireman’s outfit

Provisions for helicopter facilities

Fire control plan

Ensuring fit for purpose status of fire extinguishing appliances (operational readiness and

maintenance is detailed in MODU Code 2009)

Number and type of portable extinguishers provided on the MODU would be based on the fire hazards

for the spaces protected.

9.1.3.3 Testing & Maintenance of critical equipment

Blowout preventer and other pressure control equipment is the most critical equipment to

avoid major accidents during drilling. Therefore the blow out preventer will be pressure tested regularly

in order to maintain its capability of carrying out its intended functions. The blow out preventer with

associated valves and other pressure control equipment on the facility shall be subjected to a complete

overhaul and shall be recertified at regular intervals based on original equipment manufacturer’s

recommendations and international standards and recommended practices.

Contractor Management (Drilling Contractor)

Management of major incident risks are by the drilling contractor on the MODU is of interest

to ONGC, and will, therefore, ensure that all major incident risks have been assessed and suitable

controls put in place to reduce the risks to as low as reasonably practicable (ALARP). Pre-mobilization

and pre-drilling assessments will be undertaken by ONGC to ensure that the risk to an individual worker

is as low as reasonably practicable. Typically this is demonstrated through the analysis and summation

of all the individual risks and how they impact different classes of offshore personnel.

The major incident risks for which some level of risk assessment is undertaken normally include:

Hydrocarbon releases resulting in fires, explosions or asphyxiation

Structural failure (environmental overload, foundation failure, seismic etc.)

Mooring failure (loss of station keeping and secondary impacts)

Ship Collision

Helicopter operations

Lifting operations and dropped objects (with major incident potential)

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The nature of the risk assessment exercise undertaken for each of the risk types varies from

analysis of past incident data, to the detailed assessment of blast overpressure resulting from

hydrocarbon releases of varying sizes and from different locations.

9.1.3.4 Selection of Support Services

The proposed drilling operations will require some level of 3rd party support services which

typically include helicopter operations, standby and supply vessels, services and equipment on the rig,

onshore supply base and so on. Associated with each of these activities some level of risk assessment

will be undertaken by ONGC. These risk assessments will, for example, drive the need to develop

‘bridging arrangements’ between the contractors that contribute to the management of a particular activity

and the risks that arise from it. However, since ONGC is an experienced E&P operator owning and/or

contracting such support services – Risk Management is built in selection, supervision, and monitoring

these support services.

9.1.3.5 Ensuring Marine Integrity

1. Stability:

ONGC will ensure that floating facilities are in accordance with the requirements contained

in the applicable standards concerning stability, water tightness and watertight and weather

tight closing means on mobile offshore units.

There will be weight control systems on floating facilities, which will ensure that weight,

weight distribution and centre of gravity are within the design assumptions and equipment

and structural parts will be secured against displacements to affect stability.

2. Anchoring, mooring and positioning:

Floating facilities will have systems to enable them to maintain their position at all times and,

if necessary, be able to move away from the position in the event of a situation of hazard

and accident.

Dynamic positioning systems will be designed in such a manner that the position can be

maintained in the event of defined failures and damage to the system, in case of accidents.

During marine operations, necessary actions will be taken in such a manner that the

probability of situations of hazard and accident is avoided and those who take part in the

operations are not injured.

Requirements will be set to maintaining position in respect of vessels and facilities during

implementation of such operations, and criteria will be set up for commencing and

suspension of activities.

3. Collision risk management

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The Offshore Installation Manager will be the overall authority for safe operations within the

safety zone of installation.

ONGC will ensure that a collision risk management system is implemented and maintained

wherein following shall be inter alia included –

suitability of attendant vessels and off take tankers and competence of their crew;

assessment of probability of collision peculiar to the installation and its location;

provision of necessary risk reduction and control measures;

appropriate procedures and communications for managing operations of attendant

vessels developed jointly with marine service providers;

provision of appropriate equipment and procedures for detecting and assessing the

actions of vessels intruding into the safety zone;

provision of competent personnel with an appropriate level of marine knowledge;

provision of appropriate evacuation and rescue procedures and facilities; and

regular audit and updating of the above systems.

4. Control in the safety zone

The master of the attendant vessel or off take tanker will comply with instructions of the

Offshore Installation Manager when in a safety zone.

The master of the attendant vessel or off take tanker will be responsible for safety of his

crew, the safe operation of attendant vessel or off take tanker and for avoiding collision with

the installation or associated facilities.

5. Operations in rough weather conditions

The operator will ensure safe working in adverse weather and tidal conditions and identify

the rough weather conditions when the operations are to be discontinued and evacuations

carried out, as required.

The operator will ensure that transfer of personnel and cargo between the vessel and

installation is carried out under safe weather conditions and such transfers should be

stopped during adverse or unsuitable weather conditions

6. Cargo management

The operator will ensure optimization of cargo trips, from and to the shore, and cargo handling time at

installation by efficient planning of cargo supplies through containerization, pre-slinging of cargo etc.

9.1.4. H2S Emission Control Plans

H2S production is not envisaged in these wells, but due to exploratory nature of the wells, contingency

plan for emergencies are provided herewith:

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9.1.4.1 Detection and Alarm Systems

The system comprises of H2S sensors located at pre-determined points. In air conditioned or

ventilated areas, detectors will be installed at the fresh air inlets (ducts, entrance ways etc.). Outside,

detectors are required to be installed on gas carrying equipment (well nipple, shale shaker, mud, pits,

drillers’ stands etc.).

The alarm systems are located near potential leaks, such as the shaft gland connection,

flanges etc. It is pure alarm system with two warning stages and cannot trigger emergency shutdown

alone. The two levels of alarm are as follows:

10 ppm H2S level alarm triggers a light signal but does not indicate danger for all. At this

stage persons are instructed to stand by to check the installation after announcement on

public address system (PA) by the tool pusher, otherwise, to proceed to the upwind side

20 ppm H2S high level triggers a sound alarm and also red light on the control panel.

Emergency alarm is sounded by two short rings of bell intermittently. At this stage breathing

equipment is to be used immediately and the hazard area be vacated unless the tool pusher

give other instruction or announcement over the Public Address System.

H2S Conditions H2S (ppm) measure from Danger

to Life Action

Open air Core/Drill string

Normal operations No H2S potential None None

Watch Potential H2S None Monitor

Alert 1 - 19 NA None Monitor, use PA as needed

Danger 20 - 49 >20 Moderate Stop coring operation

Emergency >50 NA Extreme Evacuate to safe areas

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9.1.4.2 Visual Warning Signs

In case of high level H2S alarm, the following warning signs should be displayed to alert helicopter and

vessels in the vicinity of the drilling rig.

Red flag 90cm X 60 cms on each side of the rig.

Danger boards painted yellow with black lettering 30 cms high indicating "DANGER H2S".

9.1.4.3 Muster Stations and Escape Route

Since H2S is heavier than air, it is likely to settle down at lower levels particularly in still air or

in light winds and cut off the natural escape route to the boat landing; in this situation following is

practiced:

Sufficient stair cases on the upwind side of prevailing winds for escape route up the stairs

or down to the lifeboat.

Muster stations for operating personnel in the event of gas alarm areas, in the open on the

upper deck which can be kept free of H2S by the wind.

9.1.4.4 Ventilation

Forced air ventilation to disperse any accumulation of H2S will be provided by fans (bug blower) at the

following points:

Shale shaker

Working platforms

Control rooms

9.1.4.5 H2S Kick control

The control of H2S kick may be achieved either by bulldozing gas back into formation or

circulating it out. The actual method to be adopted will depend upon the condition of the well. When a

gas kick occurs, estimate the quantity of H2S present taking adequate precautionary measures of wearing

self-contained breathing apparatus (SCBA). The following procedure is to be adopted:

Close BOP, monitor SIDPP, SICP & pit gain.

If the concentration is high and cannot be circulated out due to H2S hazard in atmosphere,

bulldoze the gas into formation by pumping through kill line.

Raise mud wt. and pH as required.

Load H2S scavenger like zinc carbonate and ironite sponge as may be necessary in the

active mud pit.

Circulate the gas through choke and degasser and burn off the gas.

The following factors are needed to be kept in view:-

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All persons on the drilling floor, shale shaker area, mud pump and tank should put on

self-contained breathing apparatus when the kick is to be circulated out.

Persons who are not required for the control operation are withdrawn to a safe area,

where adequate ventilation is arranged.

Frequent checks with portable H2S gas detector are to be made.

Supply vessels will be directed to stay upwind on power and maintain continuous

radio and visual watch.

9.2. DISASTER MANAGEMENT PLAN

Oil & Natural Gas Corporation Limited is the premiere national oil company engaged in the

exploration and production (E&P) of crude oil and natural gas from offshore as well onshore assets in

Indian and abroad. The inherent risk in the oil well drilling and production are well known and the

management of the risks calls for systematic planning, adopting engineering practices and positive

attitude towards safety & environment protection. It was therefore, necessary to develop a Disaster

Management Plan (DMP) to facilitate necessary actions to meet emergency scenarios.

9.2.1. Purpose & Scope of the Plan

The disaster management plan would serve the following purpose

To set out the appropriate course of action to mitigate the impact of an emergency event.

The plan provides for a procedure allowing all those involved to mobilize their resources in

an orderly way and to react in time effectively.

To respond immediately to an emergency event to prevent its escalation to a disaster and

also the response in the event of such an escalation. The scope of the plan is to cover all

the emergency situations which can influence the risk under the following situations

Disasters due to natural causes Disasters due to manmade causes (external)

Floods Civil disturbances

Tsunami Terrorist Attack

Hurricane Hostage Crisis

Earthquake Bomb threats

Tornado Potential Offshore Vessel Collision

Lightning Helicopter crash on Helideck in Offshore

Disasters due to manmade causes (operational)

Helicopter crash-Ditch in sea

Fires Helicopter Emergency landing

Oil/gas well blowouts Office/Offshore accommodation fire

Toxic gas releases, Dropped object incidents

Oil / Chemical spills, Emergencies to offshore installations

Hydrocarbon Release Diving Incidents

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Explosions (unconfined, confined) Man Overboard incidents

The emergency situations mentioned above can escalate to such an extent that the required

level of response would be beyond ONGC’s own resources available within an Asset and intervention of

corporate level will be necessary to mobilize additional resources not only from various other work centres

of ONGC, but even from outsourcing services internationally. In such cases, DMP shall be activated by

the CMD, ONGC as and when, in his opinion, a national and/or international level intervention is required

for handling the crisis.

9.2.1.1 Updating and Exercises

The disaster management plan shall be updated as and when required but at least once in a

year. Also, the plan will be exercised under the chairmanship of the CMD once every year to test the

communication system, action plan and the response of all key agencies within ONGC, govt. of India and

outside resources. Accordingly, a Disaster, scenario will be simulated and the ‘Emergency Coordinators’

as defined by the plant will be required to act in a predetermined way to deal in real time with the situation.

The outcome of the exercise will be taken as input to updating the plan and improve on the lacunae, if

any, on the front of preparedness as well as to plug the loopholes to meet with emergencies of any extent

feasible. The exercise shall include the National Crisis Management Committee. If in any case the

exercise cannot be carried out due to operational reasons the same shall be done as a table top exercise.

9.2.1.2 Disaster Management Preparedness

In case of emergency, Emergency Response Plan (ERP) is activated by the installation

manger. He shall immediately bring it into the notice of the Asset/ Basin Manager/ Chief of Services for

mobilization of resources, should the emergency warrants so, beyond the capability of the installation/

rig/ vessel, as well as to activate the Disaster Management Plan constituting a part of the Regional

Contingency Plan (RCP). In order of affixing the responsibility, the Senior most Asset Manager shall be

the Chief Emergency Coordinator (CEC). In case of his absence the next Senior Asset Manager shall be

the CEC. The CEC shall, on the gravity of the emergency, inform the CMD, Director (HR)-CCEC, Director-

concerned and Director-I/C HSE for intervention of Corporate Disaster Management Group (CDMG).

Corporate Disaster Management Group (CDMG) will come into action in the following

situation when in case of an Offsite emergency, likely to have effect beyond the installation premises or

an emergency originated from outside the premises of the installation which is likely to effect the

operations of the installation and requires corporate intervention.

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9.2.1.3 On scene Coordinator

Initial Phase

One who is close enough to the scene of emergency may exercise emergency co-ordination in the

initial phase. Accordingly, the Installation Manager will assume the role of On-Site Coordinator (OSC).

Intermediate Phase

The Chief Emergency Coordinator (CEC) at Asset level may appoint a person, normally stationed at

base to take over the task of OSC at Site Control Room (SCR).

Function

The OSC will make an assessment of the situation; the type and quantity of assistance

required and communicate the same to the Asset ECR. The OSC will mobilize the resources available at

the site, deal with the situation and take such actions as directed by the Chief Emergency Coordinator at

the Asset/ Basin/ Plant. He will transmit situation reports (SITREPS) at regular interval prefixing a

numerical sequence to each message.

9.2.1.4 Site Control Room

Location

The Site Control Room will function at the installation depending upon situation. Alternate site control

room will be set up at the closest installation.

Mobilization

The On-Scene Co-coordinator (OSC) will set up SCR as soon as he becomes aware of the emergency

situation.

Function

To make situation reports (SITREPS) from time to time and take steps to fight the emergency. Determine

the type of assistance required & mobilize the same through ECR.

9.2.1.5 Communication

As effective communication is crucial for the overall success of the operation, a

communication flow-chart for such scenario is outlined herewith. In the event of a terrorist act, timely,

accurate communications will be critical for the success and survival. Timely response during emergency

is extremely important.

CEC at the work center must communicate immediately as per the flow chart for first

information in case any emergency is likely to come to the notice of media. This is to ensure that the

management has an authentic update of the emergency to reply to the media.

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9.3. OIL SPILL RISK ASSESSMENT

9.3.1. Oil spill scenarios

Exploration drilling in offshore areas implies a risk for acute spills to sea. Major incidents are

blowouts during drilling into the reservoir zone. Minor incidents include small spills of crude oil (well

releases), diesel (from the rig or from supply vessels) or hydraulic oil (from the rig). With respect to

environmental risk and oil spill emergency preparedness, the dimensioning incident is a blowout.

The oil spill scenarios have been assessed to classify into:

Most probable spill scenario

Maximum likely spill

Worst case spill

TABLE 9.3.1: OIL SPILL SCENARIOS

Spill Scenario Classification Qty. of oil spilled

Spill due to Rupture of flow lines/ hose during transfer of

diesel from supply vessel to the Drilling Rig (as such these

transfer hoses are likely to have auto shut off valve, but

presuming a scenario where this auto shut off valve is non-

functional and is manually shut off after a reaction time of

15 min)

Most probable

spill scenario

100 MT

(Instantaneous)

Spill of diesel due to collision between supply vessel and

the Jack-up drilling rig and damage to diesel storage in the

supply vessel

Maximum likely

spill

700 MT

(Instantaneous)

Spill of crude oil / condensate due to well blowout which

takes 2 days to cap

Worst case

spill

5000 MT (over a

period of 2 days)

9.3.1.1 Marine & Coastal Features Sensitive To Oil Spills

The block MB-OSN-2005/3 is approximately at a distance of over 160 km off the coast of

Mumbai where no ecologically sensitive areas in the exploration area lie. However, the Marine National

Park and the Marine Sanctuary that lie in the gulf will not come in the specific activities for exploratory

drilling in the block MB-OSN-2005/3. Besides this, the Maharashtra coastline comprises of significant

mangrove patches which could also be sensitive to oil spills in case of large oil spill. The well proposed

to be drilled in this block which is closest to this coast is at a distance of over 160 km.

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9.3.1.2 Assessment of Risks Due To Oil Spills

In absence of sufficient met-ocean data and an oil spill trajectory model validated to Indian

metocean conditions, the assessment of risks due to oil spills is made on the basis of logical analysis.

Quantitative spill trajectory models have not been used as part of this assessment. This assessment is

with respect to seasonal trend of coastal currents. A recent study on “Intra-seasonal variability of coastal

currents in India” (by SSC Shenoi, INCOIS – Dec’10) indicates that except during the period June to

October of the year, sea currents around the coast (excluding the gulf) are pre-dominantly towards the

northwest. During the monsoon period (i.e., Jun to Oct), the currents are predominantly towards

southeast.

Considering this, accidental spills from the proposed oil and gas drilling activity in this block

are not likely to hit the coast during the weather window generally chosen for deploying offshore rigs and

undertaking drilling activities. Moreover the nearest well (from the coast) proposed to be drilled is at a

distance of over 160 km from the coast. Therefore the risk of oil spills due to the proposed exploratory

drilling activities in this block is negligible / nil. However, considering the coastal sensitivities, ONGC

understands that preparedness to respond to oil spills during exploratory drilling program is key for

exploratory drilling.

9.3.1.3 Oil Spill Contingency Plan

Since accidental spills of crude oil and oil based products pose risks to human health and

environment, ONGC will make every effort to prevent accidental oil spills and to clean them up quickly in

case such accidental spill occurs.

The entire offshore facilities are designed, installed and operated in such a way, so as to

minimize possibility of any accidental oil spills. Facilities and resources supplied by outsourced agencies

also meet international pollution prevention design and operation standards. Oil spill risks are identified

and measures to prevent and contain oil spills have been outlined in contingency plan given below:

To establish response procedures for oil spills

To combat, contain, recover, cleanup and dispose of the spilled oil

To provide training and drill schedule for keeping the system in place, and

To meet statutory requirements

Activation of plan starts with notification of “Oil Spill” and spill assessment. Immediate action

is taken to disconnect the source. Further action is taken based on Short Term and Long Term strategies

for spill containment.

Oil Spill Response

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In any marine oil spill response, mobilization of resources depends on a number of factors.

One of the most critical ones is the time taken to activate this plan and mobilize equipment & resources

to the scene of the spill. To ensure efficiency in response initiation, a tiered response approach is adopted

by ONGC in line with NOSDCP and Oil Industry Safety Directorate (OISD) guidelines. This plan takes

into account the response time needed to mobilize, transport and deploy increasing amounts of resources

to the scene of a spill, depending upon the severity of oil spill.

The size, location and timing of an oil spill are unpredictable and different situations require

different responses. The severity of an oil spill incident is largely based on the quantity of oil spilled and

its distance from the shore. With increasing size of spill and decreasing distance from shore the number

of outside agencies involved and urgency of their notification increases and so does the resources

required and degree of organization needed. Based on past experience of oil spills, the strategy and

guidelines for dealing with different sizes of oil spills, Tier wise classification of resources have emerged.

But these tier levels were varying from place to place and company to company based on different

interpretations. In India, considering these differences, guidelines has been provided by Oil Industry

Safety Directorate (OISD), Ministry of Petroleum & Natural Gas to enable oil companies to plan their

respective tiered response strategy.

ONGC follows a 3-tier approach for oil spill response: Tier 1, 2 and 3. These are explained in

following sections.

Tier I:

In line with the standard industry practice, ONGC is prepared to mitigate spills of importance

from routine operations (Tier-1), while oil spill situations of higher magnitude are dealt with industry co-

operation and external intervention. Oil spill is considered as Tier 1 when it is less than 100T and is up

to 500 m around its installations. ONGC will immediately respond to combating such oil spill incidents

and will continue to provide equipment, material, trained manpower, sampling efforts, and vessels.

ONGC’s IMR (Inspection, Maintenance & Repair) Division is operating four numbers of Multi

Support Vessels (MSV) in the Western Coast. One of the functions of MSVs is to handle oil spills. The

following facilities exist with ONGC.

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TABLE 9.3.2: OIL SPILL RESPONSE EQUIPMENT WITH IMR, ONGC (TIER –I FACILITY)

Sl.

No.

Item Availability

in the field

At Nhava Remarks

1 Oil Spill

Dispersants

20 M3 Type-II OSD available on MSVs and at Nhava

Store.

2 Heavy Duty

Containment

Booms

500Mtrs each

(M-36, HAL

Anant &

Seamac-II)

500 mtrs

(S/Sevak)

MSV S/Sevak-500 mtrs of heavy duty oil

containment boom (Make -Lamor), kept at

Nhava Supply Base

MSV Mal-36-500 mtrs available on board

(Make-Seacurtain)

MSV HAL Anant -500 mtrs available on board

(Make-Canadyne).

Seamac-II-500 mtrs available on board

(Make –Kepner)

3 Skimmer Sets 3 (M-36, HAL

Anant &

Searnac-II)

1 (S. Sevak) MSV S/Sevak (Make- Lamor),

MSV HAL Anant (Make-Canadyne),

Malviya-36 (Make-Seavac HD Delta),

Seamac-II (Make-Kepner)

4 Ship Borne

Dispersant

Spray System

7 sets One each on S/Sevak, and Prabha and five

on chartered vessels-Hal

Anant, Mal-36., Mal-25 Mal-27 and Seamac-

II

Tier II:

Oil spill is considered as Tier II when it is more than 100T but less than 700T. ONGC will

immediately inform Coast Guard about such oil spill incidents as they are the national agency for ensuring

marine environment security in India.

Coast Guard is involved in protection and preservation of the environment and prevention and

control of pollution. Being the national coordinator in oil spill response, it has a variety of responsibilities

under the National Oil Spill Disaster Contingency Plan (NOS-DCP). It is the coordinator for oil spill

response in the entire maritime zones of India with specific allocation for direct response functions in the

maritime zones outside the port limits and notified areas around offshore oil facilities.

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TABLE 9.3.3: POLLUTION RESPONSE EQUIPMENT HELD AT COAST GUARD POLLUTION

RESPONSE TEAM (WEST), MUMBAI

Sl.

No.

Pollution Response Equipment at PRT ( West),

Mumbai

Qty. (No.) Remarks

1 RO Boom OSA 2000 with deck Reel 4 200 m each

2 RO Boom Powerpack (old) 2

3 RO Boom Powerpack (New) 2

4 Vikoma Hi-Sprint Boom with deck Reel 4

5 Vikoma PN Diesel Hydraulic Powerpack 3

6 Vikoma Hi-Sprint Boom air blower (Echo) 2

7 Vikoma air Blower (Honda) 2

8 Vimkoma Sentinal Boom 1

9 Vikoma Sential boom 1

10 Ro Boom 610 (16 x 25) 16

11 Air Blower for sl. No. 10 5

12 Boom Washing Chamber 1

13 Fresh water Chemical Pump for Sl No. 12 2

14 Power pack for Sl. No. 12 1

15 Ro ser (Settling Tank) 1

16 RoC kean Unit 1

17 Beach Cleaning equipment 1

18 Hot water cleaner (KEW) 4

19 Hot water cleaner (L&T) 1

20 CCN-100 off loading pump 1

21 Power pack for Sl. No. 20 1

22 TC-3 Aerial spray unit with bucket 3

23 TC-3 Areal Spray Arm set 5

24 Spill Spray Pump 4

25 Spill Spray Arm (set) for Sl. No. 24 5

26 Wide Spray System 2

27 OMI Oil Mop MK-II-9D 2

28 SS-50 Disk skimmer (Vimoma) 4

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29 Power Pack for OMI Sl. No. 28 4

30 Welosep Vertex Skimmer 2

31 Power Pack for Sl. No. 30 2

32 Desmi DEstroil Skimmer Ds-250 4

33 Powerpack for Sl. 32 4

34 Desmi Destroil Skimmer DS 210 2

35 Powerpack for Sl. 34 - 02 2

36 Dunlop Salvage Barge 100 M3 2

37 Dunlop Salvage Barge 30 M3 3

38 Linductor Oil recovery 2

39 Vikoma Sea Devil Skimmer 3

40 Powerpack for Sl. 3 3

41 Hydraulic Control for Sl. 39 - 03 3

42 Hydraulic hand pallet 3

43 Hydraulic power pack lifter drum lifter 1

44 Hand trolley 1

45 Hand trolley 1

46 Fork lift 1

47 SeaVac Heli Skimmer 1

48 Pallet Stacking System (Ex Jay=24 & Ex Godrej=32) 56

49 Container top for OSA 200 Boom reel 3

50 Oil Spill response kit 1

51 Seavac 330 Heli skimmer system 1

52 RO Boom 1

53 DS 250 Skimmer 1

54 Spill Spray equipment 1

55 Spray Pod 2

56 Spray Pod 8 750 SQN at Daman.

57 IR/UV System 2 -do

58 TC-3 Bucket with boom S/N 7584 1 841 SQN at Daman

59 Oil Water separator 1 At Vadinar

60 Petrol Engine General Purpose 1

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61 Rop Mop skimmer(Diesel engine & power pack) 2

62 Oil Spill Kit with accessories 2

63 Dunlop Dragon Barge 30 Ton .3

64 Sea Curtain Boom 24000 m

65 Sea vac Heli skimmer 1

66 High Pressure Steam Jet Cleaner 2

67 TC-3 Bucket 1 CGAE Goa

68 TC-3 Bucket 1 800 SQN at Goa

69 TC-3 Bucket 1 Vera flight at Kochi

Source: National Oil Spill Disaster Contingency plan (short title: NOS-DCP), 2006 (Updated),

Ministry of Defense, Government of India, CGBR 771, (Edition 2006)

Tier III:

Oil spill is considered as Tier III when it is more than 700T. Globally there are a select few

industry cooperative, international Tier 3 Response Centers. Their location was originally influenced by

the occurrence of major oil spills from shipping, these being perceived as the greatest risk. Since then

their service remit has evolved and the membership and capability have changed. While stockpiles of

equipment remain a key feature, emphasis has grown on the provision of expert staff for a range of

preparedness and response services.

For combating oil spills of this magnitude, ONGC has obtained membership of International

agency i.e. M/S OSRL (Oil Spill Response Limited), UK. The membership is continually renewed annually

to cover all ONGC’s offshore operations from the threat of major oil spills. OSRL is having expertise in

handling the disaster of any higher magnitude. They are capable of deploying their services in minimum

response time anywhere in emergency.

Strategy during first Six Hours

Depending upon nature of emergency at sea and weather conditions booms will be laid

around source of spill for containment. Recovered oil will be stored for further disposal as per laid down

procedures. If some quantity of oil has spread prior to deployment of booms or some oil has slipped away

during containment and recovery process, following factors will be taken into consideration prior to taking

decision on application of dispersant:

Spilled oil shall not be more than 4 hours old

Oil is moving towards shoreline

Spilled crude characteristics are amenable to use of dispersants

Prevailing weather conditions are conducive to dispersant applications.

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Prior approval from Coast Guard for use of dispersant will be obtained.

Spraying of Dispersants

During rough weather, monsoon, low visibility or in case of delayed deployment of equipment,

the spraying of dispersants is considered one of the options, because this strategy needs very less

reaction time (resource mobilization time) and can be initiated by the boat/vessels crew operating in the

area. Spray of dispersants can be done through Helicopters also.

Response equipment such as Containment Booms will be deployed for protection of

Maharashtra coastal belt, the creeks and mangroves along the Maharashtra coast, and sensitive pilgrim

/ tourist area of Dwarka and Bet Dwarka, to deflect spills towards other areas of the shoreline where it

shall cause less harm to the environment.

Shore Cleanup

Despite best efforts to contain and recover spilled oil, there is always a likelihood of spilled oil

reaching shorelines. Shoreline cleanup technique will be practiced for the left over oil as per topography

of the coastline.

9.3.1.4 PROJECT NEED & BENEFITS

The hydrocarbons sector plays vital role in the economic growth of the country. Oil and gas

continue to play a pre-eminent role in meeting a part of the energy demands of the country. Growth of

the economy would lead to spontaneous growth in energy consumption. Economists opine that there the

GDP and per capita energy consumption is a directly proportional. The hydrocarbon sector, therefor,

plays a crucial role in the energy security for the country.

As per the Hydrocarbons Vision – 2025 of the Ministry of Petroleum & Natural Gas, Govt. of

India, inter alia, is – ‘to assure energy security by achieving self-reliance through increased indigenous

production and investment in equity oil abroad.’ The medium term objective for E & P Sector of the country

includes:

Continue exploration in producing basins.

Aggressively pursue extensive exploration in non-producing and frontier basins for

knowledge building' and new discoveries.

Venturing into deep-sea offshore areas of the Indian basin for newer finds.

The rapid economic growth of the country and rising population result in the considerable

increase in demand of petroleum products. The gap between supply and availability of crude oil,

petroleum products as well as gas from indigenous sources is likely to increase over the years.

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The growing demand and supply gap would require increasing emphasis on E&P sector to

pace keep with demand-supply relationships.

At present, India meets about 30% of petroleum requirements from all of its resources. It is,

therefore, impertinent to expedite exploration activities to minimize our dependence on the imports and

to ensure the energy security of our country.

In view of the unfavorable demand-supply balance of hydrocarbons in the country, ONGC has

been intensifying its E&P activities in Indian basins to improve on the domestic productivity of oil and gas

as well as make equity oil available by acquiring gas assets overseas with a focus on oil security.

The Western Offshore area has been the main contributor of domestic hydrocarbon

production the Indian exchequer. The recent finds and discoveries have given new vistas and the

likelihood of finding potential hydrocarbon pools is quite high here in the basin.

Block MB-OSN-2005/3 is located in the Western Offshore basin and is proposed by ONGC

for exploratory drilling to explore for the liquid gold. In view of prognosticating the feasibility of presence

as well as tapping hydrocarbon, this offshore exploratory project is of immense domestic and national

importance.

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Chapter 10

ENVIRONMENT MANAGEMENT PLAN

The Environmental Management Plan is a site specific document for ONGC’s Offshore Drilling

Project in Arabian Sea developed to ensure that the project can be implemented in an environmental

sustainable manner and where all contractors and related stakeholders understand the potential

environmental impacts and risks arising from the proposed project and take appropriate actions to

properly manage them.

The EMP will be taken as a guide to optimize its management of all aspects of ONGC’s

activities in the MB-OSN-2005/3 Block in the Arabian Sea and activities related to the operations of its

onshore project base at Nhava. The EMP describes inter alia the actions in terms of:

Regulations and Standards

Best Practices and guides

Local Environmental and Social Sensitivities

International Conventions and National Policies

10.1. SELECTION OF DRILLING LOCATION AND NAVIGATIONAL PATH WAYS

Proper site selection and routing of navigational pathways for drilling rig and supply vessels

can result in preventive mitigation measures that may considerably reduce impacts arising out of the

proposed project. The Project planning team will work in close cooperation with the HSE Department to

look at preventive options early in the project life cycle based on findings of the EIA study. This will ensure

optimizing the need for “end-of-the-pipe” solutions to the extent feasible. Some of the proposed mitigation

measures that need to be adopted are discussed below.

Setting of Exploratory Block and Drill Locations

As has been elaborated earlier, there exists no designated marine protected areas or marine

archaeological sites in and around the project block. The project location, therefore, is not bound by any

national and international siting regulations. Occurrence of sensitive species in close proximity or within

the block will also govern the selection of drilling locations. If sensitive species viz. sea turtles are

anticipated in the block area, their presence will be monitored in accordance with the international sighting

guidelines for marine mammals.

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Selection of Navigational Pathway for Drilling Rig & Supply Vessels

ONGC will be giving due weightage to the impacts that may arise due to movement of supply

vessels (SOVs) and drilling rig, which will be documented prior to the exploratory operations and planned

taking into account MARPOL designated sensitive areas and also marine habitats protected by national

legislation. Appropriate measures will be adopted by the project proponent to avoid migratory routes of

turtles and ecologically and culturally sensitive coastal areas during vessel movement. In addition,

consultations with different stakeholders (Directorate of Fisheries, Coast Guard, Port Management

Board, etc.) will be carried out to aid in the routing of supply vessels from the logistic base.

10.2. ATMOSPHERIC EMISSIONS

There are a number of sources of atmospheric emissions (both point sources and fugitive

emissions) from the proposed offshore project. The primary air pollutant emission source for the proposed

project is DG sets. Five DG sets for meeting power requirement (~600 KW/day) will be in operation during

the exploratory period with estimated fuel consumption of 15 Kl/day/rig. The following specific mitigation

measures are recommended:

All equipment would be operated within specified design parameters during drilling

operations and fully trained personnel will be utilized to maintain and test the systems;

The project will monitor and record fuel use for compressors and generator sets.

The emissions from DG sets will be in accordance with the guidelines in MARPOL.

Valves, flanges, fittings, seals and packing considering safety and suitability requirements

will be selected to reduce gas leaks and fugitive emissions. Additionally, leak detection and

repair programs will be implemented;

Flaring of gas during well testing will be minimized and restricted to a short duration;

Flare combustion efficiency will be maximized by controlling and optimizing flare

fuel/air/steam flow rates to ensure the correct ratio of assist stream to flare stream; and

Dry, dusty materials (chemicals), mud etc. would be stored in bags or sealed containers;

10.3. STORAGE AND HANDLING OF CHEMICALS AND SUPPLIES

ONGC will ensure proper storage and handling of chemicals and other supplies at the onshore

facility at Nhava base, prior to their shipment to the rig. A good working inventory will help minimize

impacts that may arise due to such handling and storage. All loading and unloading activities will be

carried out as close as feasible to the storage facilities.

It will be ensured that lids of all containers containing volatile substances/chemicals are

properly fitted.

128

All chemical storage areas to have proper bunds so that contaminated run-off cannot escape

as runoff into the nearby coastal areas. Regular inspections to be undertaken for the storage areas to

detect any indication of leakage, decomposition or other unsafe storage conditions and corrective actions

initiated accordingly.

Adequate Personal Protective Equipment (PPEs) shall be provided to all workers involved in

handling of hazardous materials.

10.4. MANAGEMENT OF DRILL CUTTINGS & DRILLING MUD

The offshore exploratory drilling project is likely to generate a considerable amount (Total

volume during drilling of the well ~ 700 m3) of drill cuttings. The disposal option for such drill cuttings

generated from offshore drilling will primarily be governed by the type of drilling mud (water or oil based)

utilized for the exploratory drilling. The disposal of the drill cuttings to be conforming to the guidelines

pertaining to the “Disposal of Drill Cuttings and Drilling Fluids for Offshore Installations” provided by the

Ministry of Environment & Forests (MoEF) G.S.R. 546(E) August 2005. Drill cuttings disposal will be

monitored to check compliance of these guidelines.

Oil based mud will not be used unless and until warranted otherwise, and only water based

mud will be used.

To mitigate specific hole problems if SOBM is used, ONGC will ensure that it has less than

1% of aromatic content and will use with intimation to MoEF

Chemical additives used in the mud will be biodegradable (mainly organic constituents) with

a toxicity of 96 hr. LC 50 Value > 30,000 mg /l as per missed toxicity or toxicity test conducted

on locally available sensitive sea species

Hexavalent chromium compound will not be used in drilling mud. Alternative chemical in

place of chrome lignosulfonate will be used.

Except in emergency situations, bulk discharge of drilling mud in offshore will not be

undertaken. Drilling mud will be recycled to a maximum extent.

Discharge of thoroughly washed drill cuttings separated from mud & unusable portion of

mud will be discharged into sea intermittently, at an average rate of 50 bbl/hr/well to have

proper dilution & dispersion without any adverse impact on marine ecology and

environment.

Drill cuttings will not be discharged in sensitive areas notified by the Ministry of Environment

and Forests.

Disposal of drill cuttings associated with high oil content from hydrocarbon bearing formation

will have oil content < 10 gm/kg.

129

The drill cuttings wash water will be treated to conform to limits notified under EPA, before

disposal into Sea. The treated effluent will be monitored regularly.

Use of environmental friendly technology emerging due to substitution of DF or disposal

technology will be brought to the notice of MoEF and regulatory agencies and a prior

approval from Ministry of Environment and Forests will be taken

Barite used in preparation of drilling mud will not contain Hg> 1 mg/kg and Cd> 3 mg/kg.

Daily discharge of drill cuttings and drilling mud to offshore will be recorded, daily effluent

quality will be monitored and compliance reports to be submitted half-yearly to the Ministry

of Environment and Forests.

10.5 OILY WATER DISCHARGES AND OTHER WASTES

In addition to drill cuttings and unused drilling mud, the proposed exploratory drilling

operations would also result in the generation of other routine and non-routine waste streams. These

waste steams will primarily comprise of bilge fluids, ballast water, cooling water, deck drainage and food

and sanitary waste and needs to be disposed and managed in compliance with best industry practices

and international requirements to avoid any impacts arising from the same.

The waste streams which are routinely generated at offshore facilities are listed below along

with their recommended disposal measures and management alternatives:

Ballast Water

The drilling rig will be having a Ballast Water Record Book and ONGC has formulated ballast

water management procedures to a given standard. These procedures will serve as an effective

management tool in reducing the risk arising from ballast-mediated invasion. The process involved will

reduce the density of coastal organisms in ballast tanks which may be able to invade a recipient port,

replacing them with oceanic organisms with a lower probability of survival in near shore waters.

Cooling Water

In regard to the disposal of cooling water, available alternatives will be evaluated and, where

practical, the seawater intake depth will be optimized to reduce the need for use of chemicals. Appropriate

screens will be fitted to the seawater intake if safe and practical. Deck Drainage water generated from

precipitation, sea spray, or routine operations, such as deck and equipment cleaning, will be routed to

separate drainage systems on offshore facilities of the drilling rig. This includes drainage water from

process areas that could be contaminated with oil (closed drains) and drainage water from non-process

areas (open drains).

The following management measures will be followed:

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Chemicals, oils and wastes will be stored in the designated storage areas on the drilling rig

where appropriate spill cleanup materials (e.g. absorbents, containers) are maintained in

accessible locations;

In the event of a chemical or oil spill, absorbents will be used to remove spill material prior

to any washing activities;

Absorbent material, used for cleanup, will be containerized and sent to shore as hazardous

waste;

Bunding will be provided for those areas/activities where there is an increased risk of

oil/chemical spill (e.g. fuel transfer);

Material Safety Data Sheets will be made available for all chemicals used on the drilling rig

(which also includes spill response requirements);

Chemicals used will be assessed for environmental impacts prior to their purchase (e.g. fully

biodegradable detergent); and

Slops water will be discharged via an IMO approved Oil-in-water (OIW) meter as per

MARPOL requirement.

Food Waste

Food waste generated from the kitchen will be, at a minimum macerated to levels less than

25 mm as per the legal requirements prior to their discharge in the marine environment. It will also be

ensured that cleaning agents (detergents) used in the accommodation block are fully biodegradable and

inspection undertaken on a regular basis to conform to operability and performance.

As far as practicable, typical combustible and non-combustible wastes routinely generated at

offshore facilities will be segregated at source and shipped to shore for re-use, recycling, or disposal.

Efforts will be made to eliminate, reduce, or recycle wastes at all times.

The project waste management strategy being adopted to be effective solid waste treatment

hierarchy.

ONGC would ensure that the project contractor(s) have adequate training and follow

stipulated waste management procedures for minimizing, handling and storing waste; waste disposal

contractor(s) use facilities for treatment and the disposal of waste is acceptable to mitigate damage to

the environment to the permissible limit and standards.

Audits are carried out to ensure these are achieved.

Detailed waste management procedures will be put in place and all personnel employed at

the drilling rig will receive formal waste management awareness training, particularly regarding the proper

waste segregation, storage and labeling, procedures for recycling of waste.

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Quality, Occupational Health, Safety and Environmental Policy

Comply with all applicable occupational, safety, environmental legal and other requirements

of the organization.

Commitment for continual improvement in Quality, Occupational Health, and Safety and

Environmental management and performance.

Prevention of pollution due to release of hydrocarbon and other waste.

Ensure safe operations and prevent loss of property.

Protection of employees, contractual persons and persons living in adjacent areas of the rig

from the foreseeable work hazards.

Optimize the use of natural and other resources.

Maintain safe and healthy work environment.

Provide quality product and service to the customer’s satisfaction in the drilling / servicing

of well in offshore for production of hydrocarbons consistent with national and international

standards.

Be always alert and equipped to respond to emergencies and disasters by having an

updated “Emergency Response Plan” and “Disaster Management Plan”.

Equip employees and contractors with the awareness, information, instructions, and

Supervision Skills needed for safe working, quality of operation and environmental

management.

Identify and maintain the processes needed for effective implementation of the “Quality

Management System”.

10.6 MANAGEMENT MANUAL

Management of the rig describes the relevant management systems for quality occupational

health, safety, and environment in the QHSE management system manual. The management system

manual of rig establishes and maintains a quality manual that includes:

The scope of the quality management system includes all the elements of the ISO

The documented procedures for the management of quality management system have been

established for;

1. Commitment to the relevant clauses of ISO Standard

Needed by the various sections of Rig listed as documents of internal origin (DIO), these

are:-

MM manual,

132

Book of delegated powers,

R & P Regulations,

ONGC Chemistry lab procedures,

ONGC Emergency Plan (EMP).

Cementing manual,

Drilling Operational manual

Code of Safe practices Vol. I & II

Procedures needed for implementation of various clauses also referred to as Quality System

Procedure (QSP)

Check lists for the various key operations and these may be maintained by the concerned

personnel or demonstrated by them.

The details of the procedures and method of operations are developed based on the

competency of the complexity of the operations. The method of presentation of procedures aims at

enhancing the understanding of operation being done and realization of the services of drilling and testing

or the working over of wells at all stages of operation/manufacturing.

Review

The management system manual is generally reviewed at least once in a year. The review

can even be carried out in part or whole in a shorter period when the need for the same is felt due to audit

observations, change of system, change of equipment, change of management etc. The review is carried

out based on the inputs provided by a nominated manual development team. Records of such reviews

are maintained by MR/Dy MR.-QHSE.

10.7 MANAGEMENT SYSTEM PROCEDURES AND DOCUMENTATION

The rig management team documents, implements and maintains procedures for ensuring

requirements for quality, occupational health, safety, and environment in accordance with the installation

and ONGC’s stated policies. The following procedure manuals have been documented:

QHSE/DS/SSK/CPM-Common procedure manual

QHSE/DS/SSK/SPM-Safety procedure manual

QHSE/DS/SSK/QPM-Quality procedure manual

QHSE/DS/SSK/EMS/OM/01 to 04-Environment Management System and Aspect

Manual

QHSE/DS/SSK/RR- Risk Register

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Management system documentation is in the form of a written QHSE management manual

(QHSE/DS/SSK/MM).

Implementation, Operation, Infrastructure and Work Environment

The Drilling Services has determined, provided and maintained the infrastructure needed to

achieve conformity to services requirements. Infrastructure includes machineries, man power, plants,

equipment (both hardware and software) for exploratory or work over drilling operations. ONGC also

maintains marine and air logistics services, catering services, communication and information systems

for satisfactory performance in its drilling operation.

Work Environment in offshore comprises 12 hours shift duty, 14 days on-off work period

(24x7), accommodation for offices, staff and contract personnel etc. Environmental factors such as

temperature, humidity, illumination, wind speed, ventilation and weather conditions are taken care.

Resource, Roles, Responsibility & Authority

The roles, authorities and responsibilities are defined, documented and communicated to all

concerned staffs to facilitate effective QHSE Management. The Management provides essential

resources for manpower, technology and finance required for establishment, implementation

maintenance, improvement and control of QHSE Management System.

Documentation / Control of Documents

The OHSAS and EMS management system documentation includes

The OHSAS and EMS Policy and objectives and targets.

Description of scope of OHSAS and EMS.

Description of main elements of OHSAS and EMS and their interaction and reference to

related documents.

Documented procedure and records required by QMS, OHSAS and EMS standards.

Documents, including records, determined by Drilling services to be necessary to ensure

the effective planning, operation and control of processes that relate to management of its

OHSAS risk and environmental issues.

The details of the Occupational health, Safety, Environment and Quality management system

documentation are as below:

QHSE Management manual (QHSE/DS/SSK/MM) - This manual provides the outline for the

quality, occupational health, safety and environment management systems and describes

the commitment to adoption of elements as per the requirement of ISO9001, OHSAS18001

and ISO14001.The manual also provides the cross references to the relevant procedures.

134

Common Procedure Manual (QHSE/DS/SSK/CPM) - This manual, inter alia, defines the

detailed procedure of applying each element defined in the QHSE Management manual.

Quality Procedure Manual (QHSE/DS/SSK/QPM) - This manual contains all the quality

procedures (operating work instructions) to address the significant quality issues.

Environment Aspect Manual (QHSE/DS/SSK/EMS/AM): This manual provides

The list of environmental aspects (QHSE/DS/SSK/EMS/AM/01)

Evaluation and significant environmental aspects (QHSE/DS/SSK/EMS/AM/02)

Objective and Targets (QHSE/DS/SSK/EMS/AM/03)

Environment management program (QHSE/DS/SSK/EMS/AM/04)

Risk Register (QHSE/DS/SSK/RR): This manual provides the master list of

Risk Assessment criteria (QHSE/DS/SSK/RR/RAC/01)

Objectives (QHSE/DS/SU/RR/OBJ/04)

Occupational and safety hazards & Evaluation (QHSE/DS/SSK/RR/HIE/02)

List of significant risk (QHSE/DS/SSK/RR/SSK/03)

Legal Register (QHSE/DS/SSK/LR/)

This register will contain the list of applicable legislation, acts, Regulations Company’s

code etc. with reference to QHSE.

135

Chapter 11

ORGANIZATIONAL STRUCTURE

AND IMPLEMENTATION FRAMEWORK

In addition to regular operational roles & responsibilities defined for the drilling services, all

personnel directly or indirectly have a role to play towards an effective environment management in the

project. Personnel responsible for environment management at the drilling project will be responsible for

implementing the HSE policy and the environment management plan. The drilling services shall co-

operate with government agencies, regulatory authorities and other stakeholders who may have

environmental concerns associated with the project.

Various key personnel involved in the oil spill in the organization and communication have

been shown in a hierarchical manner in the following Figure 11-1.

FIG. 11.1: OIL SPILL ORGANIZATION AND COMMUNICATION

136

ONGC would also set up a Safety Committee in the MODU headed by the Well Operations

Manager as stipulated by the OISD Rules. The Safety Committee would meet once a week and will

function with the following mandate:

Discuss work related health, safety and environmental issues and make suggestions for

improvement;

Undertake safety and housekeeping inspections of the MODU with a view to identify

deficiencies and recommend corrective measures;

Promote development of safety attitude amongst employees.

11.1 CAPITAL AND RECURRING COST FOR ENVIRONMENTAL POLLUTION CONTROL MEASURES

ONGC has regular procurement plans for various operations related to hiring of drilling rig

services and associated facilities. These also include cost related to various aspects related to

environmental management measures. Thus procurements related to EMP are inbuilt in the procurement

requirement of ONGC.

11.2 DISCLOSURES OF CONSULTANTS ENGAGED

For carrying out the environmental impact assessment study of the proposed oil exploration

block MB-OSN-2005/3 in Mumbai offshore, various institutions/agencies have been working in

coordination with each other.

11.3 EIA CONSULTANT ENGAGED

No consultant has been engaged for the present study. Corporate HSE (Health Safety &

Environment) Department, ONGC, 8th floor, Scope Minar, South Tower, Laxminagar, Delhi – 110 092 is

accredited to carry out EIA studies and the present study has been carried out under their active

supervision & guidance. The primary data has been provided by Institute of Petroleum Safety, Health and

Environment Management (IPSHEM), ONGC, Betul, Goa-403 723.

11.4 AGENCY ENGAGED FOR CRZ MAPPING

Since the block MB-OSN-2005/3 block of Western offshore lies much beyond 12 nautical

miles, the nearest point of the boundary lies at a distance of over 255 km (~ 138 nautical miles) no CRZ

regulation was applicable in the block and therefore, CRZ mapping was not mandatory.

137

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Academy of Science Vol.X No.6 Sec.B.

141

Annexure – I

ToR issued by MoEF&CC for the NELP VII block MB-OSN-2005/3 (Scanned copy)

149

Annexure – II

150

Annexure - III

EQUIPMENT AND APPLICABLE STANDARDS

Sl. No.

Equipment Verification retirements Reference Standard

1 Drilling structure, Derick floor, sub structure, lifting equipment.

A. Derrick / structures i. Structures have been designed and fabricated by manufacturers as per API Spec 4F or equivalent. This verification should include structural safety level (refer sections 6 and B.6 of API Spec 4F). ii. Different categories’ inspection(s) of derrick, structures and drill floor have been carried out as per section 6 of API RP 4G or equivalent and OEM’s recommendations, besides Non Destructive Examination (NDE) as considered necessary. Chairmen cum managing director iii. Repair and modification of structures (if carried out, based on inspection) have been carried out as per section 7 and 8 respectively of API RP 4G or equivalent and OEM’s recommendations. Quality control of repair and modification has been ensured in line with requirements of section 11 of API SPEC 4F or equivalent. B. Drilling equipment i. Installation, inspection and maintenance of IC engines have been carried out as per API Spec 7C-11F or equivalent and OEM’s recommendations. For minimizing potential fires and/or explosions in the operations of IC engines requirements given in Appendix A of API Spec 7C-11F or equivalent, are being followed. Functional testing of safety devices and emergency stop function has been carried out. ii. Design, inspection and operating limits of drill stem components is as per API RP 7G or equivalent. iii. Design of drilling equipment (rotary equipment, slush pumps, power tongs and draw works) is as per API Spec 7K or equivalent. iv. Inspection, maintenance and repair of rotary equipment, slush pumps, power tongs and draw works has been carried out as per API RP 7L or equivalent and OEM’s recommendations. Inspection has included NDE and/or opening of equipment as considered necessary. Functional testing of safety devices and emergency stop function has been carried out. v. Design of drilling hoisting equipment is as per API Spec 8A and API Spec 8C or equivalent. vi. Inspection, maintenance and repair of hoisting equipment are as per API RP 8B or equivalent and OEM’s recommendations. Inspection of hoisting equipment has focused on structural integrity and personnel protection. Category III and IV inspection has included NDE / MPI and/or opening of equipment as considered necessary. Functional testing of safety devices and emergency stop function has been carried out.

API Spec 4F (3rd Edition 2008) API RP 4G (3rd Edition, 2004) API RP 4G(3rd Edition, 2004) API Spec 4F (3rd Edition 2008) API Spec 7C-11F (5th Edition 1994) API RP 7G API Spec 7K API RP 7L API Spec 8A and API Spec 8C API RP 8B

151

vii. Minimum requirements and terms of acceptance of steel wire ropes as per API Spec 9A / ISO 10425 or equivalent are being followed. viii. Field care (inspection) and use of wire rope and evaluation of rotary drilling line has been carried out as per API RP 9B or equivalent. ix. Inspection of piping and piping systems has been carried out as per API RP 570 and API RP 574. x. Pressure vessels have been inspected externally and internally; thickness measurement / crack detection tests have been carried out as deemed necessary. Pressure testing at a pressure equal to maximum allowable working pressure has been carried out. Safety valves / instrumentation have been tested.

API Spec 9A / ISO 10425 API RP 9B API RP 570 and API RP 574

2 Well Control Systems: blow out preventers, diverters, marine risers, choke and kill system, control systems for well control equipment.

A. Design of drill through equipment / blowout prevention equipment – ram and annular blowout preventers, hydraulic connectors, drilling spools, adaptors etc. is as per API Spec 16A / ISO 13533 or equivalent. Records of maintenance (including major inspection as per section 17.10.3 of API RP 53 and OEM’s recommendations) have been reviewed. Installation and testing (complete performance testing including functional and pressure tests) of blow out control equipment is being carried out in line with API RP 53 or OISD-RP-174 or equivalent. B. Design and maintenance of diverter systems is as per API RP 64 or equivalent. Inspection and testing of diverter systems has been carried out as per API RP 64 or OISD-RP-174 or equivalent. C. Design of choke and kill systems are as per API Spec 16C or equivalent. Pressure testing of choke and kill systems is being carried out in line with API RP 53 or OISD-RP-174 or equivalent. Flexible choke and kill lines and choke manifold are inspected as per section 17.10.3 of API RP-53(3rd Edition 1997) and OEM’s recommendations. D. Design of control systems for well control equipment and diverter equipment is as per API Spec 16D and API RP 53 or equivalent and performance requirements/ testing, inspection and maintenance is as per API RP 53 or OISD-RP-174 or equivalent and OEM’s recommendations. E. Marine drilling riser systems for floating drilling operations have been selected, operated and maintained in line with API RP 16Q or equivalent. Design, manufacture and fabrication of marine drilling riser system and associated equipment used in conjunction with a subsea blowout preventer (BOP) stack are as per API Spec 16F or equivalent. Design and standards of performance for marine drilling riser coupling is as per API Spec 16R or equivalent. Risers and riser couplings / joints are being inspected for wear, cracks and corrosion; thickness measurement has been carried out as required.

API Spec 16A (3rd Edition 2004) / ISO 13533 (2001) API RP 53 (3rd Edition 1997) or OISD-RP-174 API RP 64 or OISD-RP-174 API Spec 16C API RP 53(3rd Edition 1997) or OISD-RP-174 API Spec 16D and API RP 53 API RP 53 or OISDRP-174 API RP 16Q API Spec 16F / API Spec 16R

3 Man riding equipment Selection of man riding equipment is done ensuring that equipment is suitable for man riding operations, and the equipment are inspected and maintained regularly

152

4 Station keeping systems: anchoring, mooring, dynamic positioning, compensator and disconnection systems.

Verify that MODU’s station keeping and stability characteristics are suitable for the environmental (including sea bed and soil conditions) and operating conditions envelope. Inspection and maintenance of mooring hardware is as per API RP 2I or equivalent and OEM’s recommendations; and design, manufacturing and maintenance of synthetic fiber ropes for offshore mooring is as per API RP 2 SM or equivalent.

API RP 2SK (for station keeping) MODU code (for stability) API RP 2I API RP 2 SM

5 Drilling fluid handling and cementing system

Physical condition of the equipment is satisfactory and instrumentation, safety alarms and pressure safety valves are being tested regularly.

6 Electrical Systems A. Design and maintenance of electrical systems is as per IMO MODU code meeting requirements of industry standards API RP 500 or API RP 505. B. Inspection and functional testing of emergency power system is being carried out.

MODU code API RP 500 API RP 505

7 Safety systems (exclude items which are covered by MODU safety certificate, provided the rig has valid MODU safety certificate

A. Inspection and testing of the following safety systems is being carried out periodically: − Fire detection system − Gas detection system – HC and H2S − Drilling operations related alarm system − Lifesaving appliances − SCBA − Gas measuring devices − Firefighting system − Communication systems B. Safety systems are as per MODU code requirements, as applicable.

8 Cranes (If classed certificate notation does not cover cranes)

A. Design and testing of pedestal mounted offshore cranes are as per API Spec 2C or equivalent. B. Operations and maintenance of offshore cranes are as per API RP 2D or equivalent. Inspection has focused on structural integrity and includes: − Blocks and sheaves − Wire ropes and end attachments − Hooks − Bearings − Shackles − Securing arrangements − Support structure − Axle pin and housing C. Inspection and function testing has included: − Correct adjustment of brakes − Resistance measurement of electrical systems − Leakages in hydraulic systems D. Load charts have been verified by carrying out load tests as per applicable requirements. Functional testing of safety devices and emergency stop function are being carried out

API Spec 2C API RP 2D

9 Helideck (If classed certificate notation does not cover helideck)

Inspection has included: − Structural integrity of deck and supporting structure − Surface of deck − Obstacles and marking − Safety net − Fire safety arrangements

153

Annexure - IV

COMPARATIVE ECOTOXICITIES

Comparative ecotoxicitities (96 hrs LC50 values) of SPP of 15 different system drilling fluids

for one species of sensitive pawn (Penaeus monodon) and one species of fish (Mugil cephalus) are

summarized in the following table.

Comparative 96 hrs LC50 values (ppm) of different WBM samples in response to species of prawn (Penaeus monodon) and fish (Mugil cephalus).

Sample

No. Drilling Fluid System

Test Species Permissible

Limit* P. monodon M. cepjalus

Clay Free Non Damaging System ppm (%) ppm (%) (%) or (ppm)

1 KCL-PHPA System 103,100 10.31 113700 11.37 >3.0% or >30,000

2 CL-CLS System 77,700 7.77 77800 7.78 >3.0% or >30,001

3 HTHP System 84,100 8.41 87800 8.78 >3.0% or >30,002

4 Biopolymers System (TSP) 97,200 9.72 83600 8.36 >3.0% or >30,003

5 KCL-KOH-K-Lignite System 81,900 8.19 93000 9.30 >3.0% or >30,004

6 Potassium Formate System 62,100 6.21 53000 5.30 >3.0% or >30,005

7 KCL-Polyol System 58,600 5.86 47600 4.76 >3.0% or >30,006

8 Sodium Formate System 37,100 3.71 46000 4.60 >3.0% or >30,007

9 Low Lime System 102,400 10.24 121900 12.19 >3.0% or >30,008

10 Choline Chloride based System 120,200 12.02 112500 11.25 >3.0% or >30,009

11 Mixed metal oxide System 55,100 5.51 56600 5.56 >3.0% or >30,010

12 HGS System 50,900 5.09 48700 4.87 >3.0% or >30,011

13 Silicate Mud System 44,100 4.41 46100 4.61 >3.0% or >30,012

14 Low Toxic mineral Oil based Mud

system

255,200 25.52 261100 26.11 >3.0% or >30,013

*Permissible limit (96 hrs LC50) as specified by the Ministry of Environment and Forests, Govt. of India vide G.S.R. 546 (E)- dated 30th August, 2005 is >30,000 mg/l or >3.0%

The 96 hrs LC50 values of 15 water based drilling fluid systems to post larvae of black tiger

prawn (Penaeus monodon) were found to be range from 37,100 ppm (3.71%) for KCL-Polyol System to

255,200 ppm (25.52%) for Silicate Mud System drilling respectively. On the other hand, 96 hrs LC50

values of different drilling fluid systems tested using larvae of grey mullet (Mugil cephalus) were found to

be range from 46,000 ppm (4.60% for KCL-Polyol System to 261,100 ppm (26.11%) for Silicate Mud

System, respectively.

The determined median lethal concentrations (96 hrs LC50 values) for all the drilling fluids to

two tested species fell within the acceptable criterion of >30,000 mg/l (>3.0%) as stipulated by

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EPA/MoEF. Further, the of toxicity indices of 15 drilling fluid sample supplied by Institute of Drilling

Technology (IDT) of Oil and Natural Gas Corporation Limited (ONGC), Dehradun was assessed by

comparing the median lethal concentrations (96 hrs LC50 values) obtained for post larvae of prawn and

fish larvae against the Toxicity rating classification system used by EPA/NPDES (Table below).

Toxicity testing classification system used by EPA/NPDES

Category Median lethal concentration (LC50)

Non-toxic (NT) >100,000 mg/l

Practically Non-toxic (PNT) 10,000-100,000 mg/l

Slightly-toxic (ST) 1,000-10,000 mg/l

Moderately-toxic (MT) 100-1,000 mg/l

Toxic 1-100 mg/l

Very toxic < 1 mg/l

(Hindwood et al., 1994)

The toxicity indices determined for prawn post larvae and fish larvae belonged to the ‘Non-

toxic’ category as per the toxicity testing classification used by EPA/NPDES (Table 36). Therefore, it is

concluded that based on acute toxicity test results on local sensitive sea species, the water based drilling

fluid sample provided by The Institute of Drilling Technology (IDT) of Oil and Natural Gas Corporation

Limited (ONGC), Dehradun is acceptable to EPA/NPDES/BAT/MoEF for its use and discharge in

offshore/onshore drilling operations.

Source: Institute of Drilling Technology (in-house Report 2013).

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