environmental impact assessment...

SPDC Table of Contents

EIA of Benisede Catchment Area FDP Phase 2 June, 2005 II

The Shell Petroleum Development Company of Nigeria Limited

Operator of the NNPC/Shell/Agip/Total Joint Venture

ENVIRONMENTAL IMPACT ASSESSMENT (EIA)

of

BENISEDE CATCHMENT AREA FDP PHASE II

FIELD DEVELOPMENT PLAN

FINAL REPORT

Report: SPDC 2004-0044442 (b)

JUNE, 2005


EIA of Benisede Catchment Area FDP Phase 2 June, 2005 III

STATUS PAGE

Title: ENVIRONMENTAL IMPACT ASSESSMENT (EIA) OF BENISEDE

CATCHMENT AREA FDP PHASE II FIELD DEVELOPMENT PLAN

Originator: The Shell Petroleum Development Company of Nigeria limited

Author: EPG-PN-CFHEV/EPG-PN-CFHLW

Approved by: EPG-PN-TTWC

Document Number: SPDC 2004-0044442 (b)

Version: 03

SECURITY: NON-CONFIDENTIAL

Change history:

Version Date Pages Reason

03 June 2005 Whole Document Incorporation of FMENV Review

Panel comments

FINAL REPORT


EIA of Benisede Catchment Area FDP Phase 2 June, 2005 IV

TABLE OF CONTENTS

TITLE PAGE

STATUS PAGE …………………………………………………………………………………………….....I

TABLE OF CONTENTS ……………………………………………………………………………….II - VII

ACKNOWLEDGEMENT………………………………………………………………………………….VIII

LIST OF PLATES …………………………………………………………………………………………...IX

LIST OF FIGURES ……………………………………………………………………………….………….X

LIST OF TABLES …………………………………………………………………………………………..XI

LIST OF APPENDICES ……………………………………………………………………………………XII

LIST OF ABBREVIATION AND ACRONYMS …………………………………………………...XIII - XV

EIA PREPARERS ………………………………………………………………………………….……...XVI

EXECUTIVE SUMMARY ……………………………………………………………………………..1 - 11

CHAPTER ONE

1.0 INTRODUCTION ……………………………………………………………………………….....1 of 15

1.1 General …………………………………………………………………………………….. …..1 of 15

1.2 The Proponent ……………………………………………………………………………….…1 of 15

1.3 Background Information ………………………………………………………………………..2 of 15

1.4 EIA Objectives …………………………………………………………………………….……2 of 15

1.5 EIA Methodology ………………………………………………………………………….…...3 of 15

1.6 Legal and Administrative Framework for EIA in Nigeria ……………………………………...5 of 15

1.6.1 Environmental Impact Assessment (EIA) Act…. ……………………………………...6 of 15

1.6.2 Petroleum Act of 1969, Section 8 (III) …………………………………………….…...6 of 15

1.6.3 Oil Pipeline Act and Oil & Gas Pipelines Regulations 1958 (Amended 1995) ………..6 of 15

1.6.4 Mineral Oils Safety Regulations 1963 (Amended 1997) ………………………….…...7 of 15

1.6.5 National Environmental Protection (Effluent Limitations) Regulation (S.I.8) 1991.…...8 of 15

1 6.6 National Environmental Protection Regulation (S.I.9) 1991………………………...….8 of 15

1.6.7 National Environmental Protection (Management of Solid Hazardous

Waste Regulation (S.I.15) 1991. ……………………………………………………......9 of 15

1.6.8 EIA Sectoral Guidelines of the Federal Ministry of Environment (FMENV) ………....9 of 15


EIA of Benisede Catchment Area FDP Phase 2 June, 2005 V

1.6.9 DPR’s Requirements for EIA …………………………………………………………11 of 15

1.6.10 Forestry Law CAP 51, 1994…………………………………………………………...13 of 15

1.6.11 Land Use Act of 1978………………………………………………………………….13 of 15

1.6.12 Delta and Bayelsa States Ministries of Environment …………………………………13 of 15

1.6.13 SPDC HSE Policy ………………………………………………………………….….14 of 15

1.6.14 Other National and International Legislation and Conventions …………………….…14 of 15

1.7 Structure of the Report ………………………………………………………………………...14 of 15

1.8 Declaration ………………………………………………………………………………….…15 of 15

CHAPTER TWO

PROJECT JUSTIFICATION …………………………………………………………………………....1 of 4

2.1 General …………………………………………………………………………………….……..1 of 4

2.2 Project Objectives………………………………………………………………………….….….1 of 4

2.3 Need for the BCA FDP Project Phase 2………...…………………………………………….….1 of 4

2.4 Benefits of the BCA FDP Project ……………………………………………………………..…2 of 4

2.5 Envisaged sustainability of the BCA FDP Project ………………………………………………2 of 4

2.5.1 Social Sustainability ……………………………………………………………………..2 of 4

2.5.2 Environmental Sustainability ……………………………………………………………2 of 4

2.5.3 Economic Sustainability …………………………………………………………………3 of 4

2.6 Project Alternatives ……………………………………………………………………………….3 of 4

CHAPTER THREE

3.0 PROJECT DESCRIPTION ……………………………………………………………….…….1 of 36

3.1 General …………………………………………………………………………………….…….1 of 36

3.2 Project Scope …………………………………………………………………………………….1 of 36

3.3 Project Location.………………………………………………………………………………...1 of 36

3.4 The proposed project Overview ………………………………………………………………...2 of 36

3.5 Surface Locations ……………………………………………………………………………….3 of 36

3.5.1 Benisede Field …………………………………………………………………….…….3 of 36

3.5.2 Akono Field……………………………………………………………………………...5 of 36

3.5.3 Opomoyo Field …………………………………………………………………………5 of 36

3.6 Proposed Project Design Philosophy …………………………………………………………...5 of 36

3.7 Engineering and Detailed Design ……………………………………………………………….6 of 36

3.7.1 Applicable Standards and Codes………………………………………………………...6 of 36


EIA of Benisede Catchment Area FDP Phase 2 June, 2005 VI

3.7.2 Quality Assurance of Design …………………………………………………………...7 of 36

3.7.3 Well Trajectory Design …………………………………………………………………8 of 36

3.7.4 Wellhead Design………………………………………………………………………...8 of 36

3.7.4.1 Horizontal Wells………………………………………………………………..8 of 36

3.7.4.2 CONVENTION DEVIATED WELLS…………………………………………9 of 36

3.7.5 Casing Design…………………………………………………………………………...9 of 36

3.7.6 Well Completion Design ………………………………………………………….. ….10 of 35

3.7.6.1 New Well Completion Design/Philosophy ……………………………….…...10 of 36

3.8 Gas lift Requirement …………………………………………………………………………...12 of 36

3.9 Production Commingling ………………………………………………………….. ………….13 of 36

3.10 Well Safety Enhancement ………………………………………………………………….….13 of 36

3.11 Drilling Rig Selection …………………………………………………………………….……14 of 36

3.12 Mud Systems ……………………………………………………………………………….….15 of 36

3.12.1 Surface Hole (16" for Conventional or 12-1/4" for horizontal) ……………………….15 of 36

3.12.2 Build Section (8-1/2" for horizontal) ………………………………………………….15 of 36

3.12.3 Production hole Section (12-1/4" for Conventional wells) ……………………………16 of 36

3.12.4 Drain Hole (6") ……………………………………………………………………..…16 of 36

3.13 Cementation…………………………………………………………………………………....16 of 36

3.14 Waste Management ………..…………………………………………………………………..17 of 36

3.15 Project Schedule ……………………………………………………………………………….17 of 36

3.16 Production Operations Plan ……………………………………………………………….…..19 of 36

3.16.1 Production Facilities ………………………………………………………….. ….…..19 of 36

3.16.2 Campaign Operations and Maintenance……………………………………………….27 of 36

3.16.3 Materials and logistics…………………………………………………………………34 of 36

3.17 Production Operations CASHES Aspects………………………………………………….….34 of 36

3.18 Well Decommissioning/Abandonment………………………………………………………...36 of 36

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EIA of Benisede Catchment Area FDP Phase 2 June, 2005 7 of 253

CHAPTER FOUR

4.0 DESCRIPTION OF ENVIRONMENT…………………………………………………………1 of 44

4.1 General………………………………………………………………………………………..…1 of 44

4.2 Description of Existing Environment…………………………………………………….……..1 0f 44

4.2.1 Relief/Topography Studies…………...…………………………………………………1 of 44

4.2.2 Climate and Meteorology Studies. ……………………………………………………...1 of 44

4.2.3 Air Quality and Noise ………..………………………………………………………….6 of 44

4.2.4 Soil, Agriculture and Land Use Studies………………………………………….……...7 of 44

4.2.5 Vegetation / Land use………………………………………………………………… 12 of 44

4.2.5.1 Vegetation profile…..…………………………………………………………………..12 of 44

4.2.5.2 Land use types ans Floristic Composition……………………………………………..13 of 44

4.2.5.3 Plant Species Diversity of the BCA FDP Area………………………………………...17 of 44

4.2.6 Wild Life / Biodiversity Studies………………………………………………………..20 of 44

4.2.7 Aquatic Studies………………………………………………………………...……….22 of 44

4.2.8 4.2.8 Sediment Studies…………………………………………………………...………...25 of 44

4.2.9 Microbiology Studies…………………………………………………………………….26 of 44

4.2.10 Geology/Hydrogeological Studies…………………………………………..….……....27 of 44

4.2.11 Social and Health Impact Studies..……………………………………………………..30 of 44

CHAPTER FIVE

5.0 CONSULTATION……………..……………………………………………………….…..1 of 3

5.1 General……………………………………………………………………………….……...1 of 3

5.2 Consultation for the BCA FDP project……………………………………………………...1 of 3

5.2.1 Consultations by the Proponent……………………………………………...……...1 of 3

5.2.2 Field Consultations by EIA/SIA/EIA Consultants…………………………..…………...2 of

3

5.3 Identified Stakeholders for the BCA FDP project……………………………….……………….2 of

3

5.4 Consultation with Regulators for the BCA FDP project…………………….……………………2 of

3

5.5 Consultation with Host Communities for the BCA FDP project……….…………….…………..2 of

3

5.6 Community Concerns about the BCA FDP project……………….………………….…………..3 of

3

5.7 Community Assistance/Community Development Projects ….………………………………….3 of

3

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CHAPTER SIX

6.0 POTENTIAL AND ASSOCIATED IMPACT ASSESSMENT.……………………………….1 of

32

6.1 General…………………………………………………………………………………………..1 of

32

6.2 Principles of Impact Prediction and Evaluation………………………………….…….………..1 of

32

6.3 Impact Assessment Methodology………………………………………………..…….………..3 of

32

6.4. Screening and Scoping of the Potential Impacts ……………………………..……….………..4 of

32

6.5 Potential Impact Evaluation…………………………………………………………….……...10 of

32

6.6 Detailed Description of Potential Impacts……………………………………………………..13 of

32

6.6.1 Rig Mobilisation……………………………………………………………..….……..13 of

32

6.6.2 Drilling………………………………………………………………………………....13 of

32

6.6.2.1 Drilling fluid and cuttings………………………………………….….……….14 of

32

6.6.2.2 Sewage and Sanitary wastes………………………………….……….……….14 of

32

6.6.2.3 Accidental Oil Spill………………………………………..…………………...14 of

32

6.6.3 Impact due to Dredging………………………………………………………………...15 of

32

6.6.4 Impact due to Flowline installation…………………………..………………………...15 of

32

6.6.5 Gaseous Emissions……………………………………………………………………..15 of

32

6.6.6 Impact on Fishing……………………………………………………………...……….16 of

32

6.6.7 Impact due to Well blow-out………………………………………………..…………16 of

32

6.6.8 Beneficial impacts………………………………………………………..……………16 of

32

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6.7 Risk Assessment……………………………………………………………..………….…….16 of 32

6.7.1 Assessment of Hazards…………………………………………...……………………17 of

32

6.7.2 Project Risk Management…………………………………………………….………..18 of

32

6.7.3 Health, Safety and Environmental Management System in the BCA…………………18 of

32

6.8 Modelling……………………………………………………………………………………....19 of

32

6.8.1 Air Quality Modelling…………………………………………………………………...19 of

32

6.8.2 Surface Water Quality Modelling……………………………………………………….24 of

32

6.8.3 Ground Water Modelling………………………………………………………………..26 of

32

CHAPTER SEVEN

7.0 MITIGATION MEASURES AND ALTERNATIVES………………………..………….……...1 of

8

7 .1 General ……………………………………………………………………..…………………….1 of

8

7.2 Process Monitoring and Control Technology…………………………..………………………...1 of

8

7.3 Impact Mitigation Measures………………………………………..…………………………….2 of

8

CHAPTER EIGHT

8.0 ENVIRONMENTAL MANAGEMENT AND COMMUNITY DEVELOPMENT PLAN…....1 of

18

8 .1 General …………………………………………………………………….………….………...1 of

18

8.2 EMP Objectives………………………………………………….…….………………………..1 of 18

8.3 Environmental Monitoring Programmes……………………….….……………………………2 of

18

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8.4 Environmental Audit…………………………………………..………………………………..5 of

18

8.5 Waste Generation/Management……….………………………………………………………..5 of

18

8.5.1 Waste Characterization /Categorization..……………………………………………….5 of

18

8.5.2 Drilling waste (Use drilling mud and cuttings)………………………………...……….5 of

18

8.6 Summary of waste management…..…………………………………………………………..11 of

18

8.6.1 Produced Water…..……………………………………………………………………11 of

18

8.6.2 Pseudo-oil-based Muds and Cuttings………………………………………………….11 of

18

8.6.3 Oil Spills………………………………………………………………………..……...11 of

18

8.6.4 Gaseous Emissions CO2, CH4, SOx, NOx, H2S, VOCs (including BTEX)..…………..12 of

18

8.6.5 Halons and CFCs……………………………………………………...………………12 of

18

8.7 Staff Resourcing and Training……………………………………………..………….……….13 of

18

8.8 Community Development Plan………………………………………..………………………13 of

18

8.9 Decommissioning and Abandonment Plan…………………………………………………….18 of

18

CHAPTER NINE

9.0 CONCLUSION………………………………………………………………………………….1 of 1

REFERENCES

APPENDICES

SPDC Chapter Three


ACKNOWLEDGEMENT

The Shell Petroleum Development Company of Nigeria Limited (SPDC) wishes to

acknowledge the opportunity granted it by the government of the Federal Republic of Nigeria

through its Agencies, to conduct this Environmental Impact Assessment (EIA) for Benisede

Catchment Area Field Development Phase II Project (BCA FDP). We have unequivocally

enjoyed the cordial working relationships with the National Petroleum Investment

Management Services (NAPIMS), our Joint Venture Partners, Federal Ministry of

Environment (FMENV), Department of Petroleum Resources (DPR), Delta and Bayelsa State

Governments, Delta and Bayelsa States Ministries of Environment, Burutu and Ekeremo

Local Government Councils, the Elders, Chiefs and Youths of the host/pipeline communities.

The contributions of BGI Resources Limited, Port Harcourt, commissioned to execute this

EIA studies is acknowledged.

The efforts of the project Team comprising representatives from various SPDC departments,

viz:- Environment (HSW-ENV), Public and Government Affairs (PRW-PAF), Geomatics

(DTW-GEM), Area Team C (PCW) and Legal (CLW LIT) are also recognized.

SPDC Chapter Three


LIST OF PLATES

PAGES

PLATE 1: A WELLHEAD IN THE STUDY AREA

12 OF 37

Plate 2: Benisede Flowstation 21 of 36

Plate 3: Soil sampling using a hand-held auger 8 of 44

Plate 4. Brass Creek –A Major drainage feature in the study area (also

showing a palm bush) 12 of 44

Plate 5:A Farmland in the study Area 14 of 44

Plate 6: Farming on dredge-spoil along bank of Bomadi Creek 16 of 44

Plate 7: Tilapia zilli caught at the Benisede Flowstation area 17 of 44

Plate 8: Drilling new groundwater quality monitoring borehole at Opomoyo. 29 of 44

Plate 9: Flushing existing groundwater quality monitoring boreholes

at the Benisede flow-station. 30 of 44

Plate 10: Consultation with communities (Ojobo) 33 of 44

Plate 11: Dugout canoes – common means of transportation of goods and

persons in the study area. 37 of 44

Plate 12: A Typical Shoreline Settlement in the Study Area – Peretorugbene 38 of 44

SPDC Chapter Three


LIST OF FIGURES

TITLE PAGE

1.1: Assessment Pattern 5 of 15

1.1: FMENV EIA Management Procedure 10 of 15

1.2: DPR Flowchart for the EIA Process 12 of 15

3.0: Benisede Catchment Area 2 of 37

3.1: Benisede prospects 3 of 37

3.2: Completion Diagram for Benisede – H 4 of 37

3.3: Completion Diagram for Benisede C and C* 11of 37

3.4: Benisede Phase 2 project Plan 18 of 37

6.1: Schematic Representation of Potential Impact Assessment Approach 2 of 32

6.2: Benisede Catchment Area Flare Emission Dispersion Model 23 of 32

6.3: Oil Spill Fate on Water Surface within Benisede 26 of 32

6.4: Groundwater Flow Direction Model from a Point source 30 of 32

6.5: Impact Flow Direction Model from a Point source 32 of 32

SPDC Chapter Three


LIST OF TABLES

TITLE PAGE

3.0: The Current Status of BCA Wells and Safety Plans 14 of 36

3.1: Current Benisede Field Completion Data 20 of 36

4.1: Main Maximum Temperature in 0C 3 of 44

4.2: Monthly Total Rainfall Records in mm 4 of 44

4.3: Mean Monthly Temperature and Rainfall Records 5 of 44

4.4: Wind Speed and Direction within BCA FDP Area (Dry Season) 6 of 44

4.5: Particle Size Distribution in Soil of BCA FDP Area 9 of 44

4.6: Agricultural Landuse types with commonest plant species 15 of 44

4.7: Plant Species diversity and agricultural landuse 18 of 44

4.8: List of Plant Species/disease analysis within BCA FDP Area 19 of 44

4.9: List of Wildlife Species within BCA FDP Area 21 of 44

4.10: A list of the commonest fish Species within the BCA FDP Area 24 of 44

4.11: BCA Community Population 31 of 44

4.12: Demographic profile of the BCA FDP Area 32 of 44

4.13: Family Size Distribution of Communities within BCA FDP Area 32 of 44

4.14: School Enrolment Statistics 2001 39 of 44

4.15: Health Risk Exposure Matrix (health Sensitivities 42 of 44

6.1: Environmental Components and Potential Impact Indicators 6 of 32

6.2: Potential and Associated Impact Identification Checklist 8 of 32

6.3: Impact Evaluation Matrix for BCA FDP 12 of 32

6.4: SPDC HSE Risk Matrix 17 of 32

6.5: Summary of emissions from the proposed flowstation 20 of 32

6.6: Maximum Concentrations for Selected Periods (hours) 24 of 32

6.7: Flow rate (current), Width and Depths across Creeks and Creeklets 25 of 32

6.8: Overburden Longitudinal Conductance and the Protective Capacity 31 of 32

6.9: Classification of Soil Resistivity in Terms of the Corrosivity 31 of 3 2

7.1: Proffered Mitigation Measures 3 of 8

8.1: Monitoring Programme for Environment Components 3 of 20

8.2: Drilling Discharge Monitoring Programme (DPR Requirement) 4 of 20

8.3: Produced water treatment systems 10 of 20

8.4: Stakeholder Register 16 of 20

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8.5: Completed and On-going CA/CD Projects 17 of 20

8.6: Current CA/CD projects Plan – Summary. 19 of 20

SPDC Chapter Three


LIST OF APPENDICES

Appendix I: Maps

Appendix II: Field Methodologies

Appendix III: Recorded Data

Table 4.1: Ambient Air Quality

Measurements…………………………………...1 of 1

Table 4.2: Noise Level and Radiation Measurements…………………………….1 of 1

Table 4.3: Physico-Chemical Characteristics of soil ……………………………..1 of 2

Table 4.3c: Texture Analysis of Soil from Benisede field…………………………1 of 1

Table 4.4: Plant Tissue

Analysis………………………………………………….1 of 1

Table 4.5: Physico-Chemical Characteristics of surface water

…………………..1 of 3

Table 4.6: Physico-Chemical Characteristics of

sediment………………………...1 of 2

Table 4.7: Summary of Heterotrophic and Petroleum Degrading Bacterial

count in

soil……………………………………………………………1 of

1

Table 4.8: Summary of Heterotrophic and Petroleum Degrading fungal

count in

soil…………………………………………………………….1 of

1

Table 4.9: Microbial analysis of surface water samples

(Bacterial)………………1 of 1

Table 4.10: Microbial Analysis of surface water samples

(Fungal)………………..1 of 1

Table 4.11: Microbial Analysis of sediment samples

(Bacterial)…………………..1 of 1

Table 4.12: Microbial Analysis of sediment samples

(Fungal)…………………….1 of 1

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Appendix IV: Detailed Environmental Legislation and Conventions

Appendix V: Evidence of Consultations

SPDC Chapter Three


LIST OF ABBREVIATIONS AND ACRONYMS

ALARP As Low As Reasonably Possible

ANSI American National Standards Institute

APHA American Public Health Association

ASME American Society of Mechanical Engineers

cfu/g Colony forming unit per gram

cfu/ml Colony forming unit per millilitre

cm Centimetre

C Carbon

Ca Calcium

CAO Computer Assisted Operations

CEC Cation Exchange Capacity

Cl Chloride

Cu Copper

CO Carbon monoxide

CO2 Carbon dioxide

COD Chemical Oxygen Demand

CPF Central Processing Facility

DEP Design and Engineering Practice

DPR Department of Petroleum Resources

E East

EGASPIN Environmental Guidelines and Standards for the Petroleum Industry in Nigeria

E & P Exploration and Production

EIA Environmental Impact Assessment

ESS Expandable Sand Screen

FMENV Federal Ministry of Environment

FAO Food and Agricultural Organization

GC Gas Chromatograph

GPS Global Positioning System

GSI Gonadosamatic Indices

GTS Gas Transmission System

HAZOP Hazard and operability

HEMP Hazards and Effects Management Process

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HNO3 Trioxonitrate (V) acid

HP High Pressure

HSE Health, Safety & Environment

HUB Hydrocarbon Utilizing Bacteria

HUF Hydrocarbon Utilizing Fungi

H2SO4 Tetraoxosulphate (VI) acid

km kilometres

m metres

mg/kg milligram per kilogram

mg/l milligram per litre

ml millilitre

MMb Million Metric Barrels

MMstb Million Metric Standard barrels

mm milimetre

MPF Mobile Production Facility

ms-1

metres per second

mS/cm Milli Siemens per centimetre

mv millivolt

N North

NAPIMS National Petroleum Investment Management Services of the NNPC

NNPC Nigerian National Petroleum Company

NE North East

NIOMR Nigerian Institute of Oceanography and Marine Research

NOx Nitrogen Oxides

NTU Nathalometric Turbidity Unit

NW North West

OHGP Open Hole Gravel Pack

oC Degree Celsius

PAH Poly Aromatic Hydrocarbon

pH Hydrogen ion concentration

ppm Parts per million

ppt Parts per thousand

S South

SE South East

SPDC Chapter Three


sp species

SPDC Shell Petroleum Development Company of Nigeria Limited

SPM Suspended Particulate Matter

SSW South South West

Stb Standard barrels

SW South West

SFAGG South Forcados Associated Gas Gathering

SSAGG Southern Swamp Associated Gas Gathering

STABOR Computer Programme for well bore stability

TFC Total Fungal Count

TDS Total Dissolved Solid

THBC Total Heterotrophic Bacterial Count

THC Total Hydrocarbon Content

UR Undeveloped Reserve

VOC Volatile Organic Carbon

W West

% Percentage

< Less than

SPDC Chapter Three


EIA PREPARERS

DR. IME UDOTONG - (TEAM LEADER) MICROBIOLOGY & WASTE

MANAGEMENT

DR AFAM ANENE - FISHERIES/HYDROBIOLOGY

DR. K. E. AKPABIO - VEGETATION/WILDLIFE/BIODIVERSITY

Dr. S. O Edem - Soil Sampling/Land use

Mr. Fidelis Effiom - Geology/Hydrogeology

Dr. V.O Ebong - Social Impact Assessment (SIA)/ Health Impact

ASSESSMENT (HIA)

MR. M. ONUORA - GEO-POSITIONING (DTW-GEM)

LABORATORY ANALYSIS - TECHNOLOGICAL PARTNERS INTERNATIONAL

LABORATORIES LIMITED (TPI)

TECHNICAL REVIEW

MR. BASSEY AKPAN

DR. IME UDOTONG

HSW-ENV (SPDC) REPRESENTATIVES

Dr. A.G. Yammama (Team Leader)

Miss. Sophia Samuel

DR. D.P.O. AGUIYI

Mr. Stephen Akeno

Phase Two: Report Review Team

SPDC Chapter Three


Miss. Sophia Samuel

Mr. Ubom Archie (Project Engineer)

Mr. Akeno Steve

Mr. Wale Adesanya

Mr. Iyegoa Igali

SPDC Chapter Three


EXECUTIVE SUMMARY

Introduction

Shell Petroleum Development Company (SPDC) intends to further develop the

Benisede Catchment Area (BCA) Field. The field development is aimed at boosting

oil output and to also test neighbouring prospects. The Benisede Catchment Area

(BCA) Field Development Plan (FDP) Phase 2 covers the lifecycle re-development

plan of the Benisede Catchment Area i.e. Benisede field and prospects as well as

Akono, Opomoyo, Osuopele and Orubou fields. The plan presents a base case

development scenario targeting 117.2 MMstb of reserves through the drilling of about

11 wells.

An Environmental Impact Assessment for the project has been carried out in

accordance with the requirement of Nigerian legislation and SPDC HSE policy.

Legal and Administrative Framework

The Benisede Catchment Area Field Development Project shall be executed within

the premise of the relevant Nigerian regulatory laws and statutes, international

conventions and SPDC policies. These include:

Acts, Regulations, Guidelines and Standards for the petroleum industry

sector.

Design and Engineering practices and SPDC standards.

International conventions and treaties to which Nigeria is signatory.

Details of the applicable laws, regulations and standards are provided in section 1.6

of this report.

The EIA Objectives

The objectives of the EIA study are:

to determine the baseline ecological conditions of the study area;

to determine the environmental sensitivities prevalent in the area;

to identify, evaluate, and predict the impact of the project on the ecological, socio-

economic and cultural settings with adequate interfacing and project interaction;

SPDC Chapter Three


to identify health hazards that may result from the different phases of the project and

evaluate local population exposure to these hazards.

to develop control strategies with a view to mitigating and ameliorating significant

impacts that the project would have on the totality of measurable environmental

characteristics;

to develop a cost effective Environmental Management Plan (EMP) for the identified

impacts.

Consultation

SPDC shall maintain the established communication and consultation links with

Regulatory Agencies and other stakeholders (Host and Pipeline Communities as well

as NGOs).

Project Overview

The Benisede Catchment Area (BCA) Field which is in the swamp, was discovered in 1973,

and based on recent 3-D seismic survey, there are plans to drill more wells in the field. The

BCA Field is a three-in-one field comprising Benisede, Akono and Opomoyo fields. The

objective of the proposed project is to develop the remaining reserves in these fields and test

neighbouring exploration prospects.

The proposed phase 2 project, shall be carried out in the Southern Swamp Area of the

Western Division of SPDC, and would involve the drilling of about 11 wells and laying

about 60km of flowlines to an upgraded Benisede flowstation. It is envisaged that about

301.9 Hectares of land will be taken for the project, which will also involve dredging

activities. About 184 weeks will be spent on the proposed project, i.e. 24 weeks on the

flowline and jacket construction phase and about 160 weeks on the drilling activities. The

well drilling phase of the project will require about 100 men on site.

Project Alternatives

Three (3) possible integrated development alternatives/scenarios were identified:

Scenario 1: No Action/Do nothing

Scenario 2: Development activity with upgraded 90 Mbpd facility

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Scenario 3: Development activity with new 90 Mbpd facility

Scenario 3 is the preferred alternative given its economic advantages and

environmental implications. This Green Field alternative gives opportunity for an

integrated oil and gas facility, and thus incorporates SPDC’s new operational

philosophy of integrated oil and gas operations. The scenario is also in line with the

Federal Government’s flares down policy. Scenario 3 is therefore an environment

friendly alternative.

Project Schedule

The BCA FDP Phase II drilling was originally scheduled to start in 2005 but is now

delayed because of alignment required with the Southern Swamp Integrated Oil and

Gas Project (SSIOGP) to harness the expected Associated Gas (AG) to the Liquefied

Natural Gas (LNG) train in line with the flares out date of 2008.

Well Decommissioning/Abandonment

All wells that have no economic value will be decommissioned and abandoned in line

with SPDC Well Abandonment Policy.

On reaching the end of the project life span, a decommissioning team shall be set up

to plan and implement the guidelines for decommissioning/abandonment to ensure

that the best and practicable methods available are employed to clean up the project

site.

Environmental Status

The environmental characteristics of the proposed project area as indicated by the

various ecological components have been carefully studied through existing maps,

meteorological reports, baseline reports and detailed field study.

CLIMATE AND METEOROLOGY

The study area is located in the Gulf of Guinea and lies in the semi-hot equatorial

zone and with distinct climatic seasons, wet and dry. The climate in the area is typical

of the equatorial rain forest with temperatures ranging between 23.1 – 22.3 o

C and

SPDC Chapter Three


30.9 – 31.5 o

C for wet and dry seasons respectively. Humidity in the area is high all

the year round.

Two main winds, southwest (SW) and the northeast (NE) winds are generally

influential on the weather in the study area. However, a third wind, the North-South

wind has also been reported in the area. The north–south wind is known to be

strongest during the dry season (November – March). It accounts for about 32% of the

annual winds within the Niger Delta area during this period. (NLNG, 1997).

Within the BCA FDP area, rain falls throughout the year but over 80% of it occur in

the months of May to September. The 25-year rainfall records (1979 - 2003) from the

Port Harcourt station indicate a mean rainfall of 373mm, 19.3 and 107.9mm for the

months of July, December and March respectively. The single highest rainfall record

is 840.9mm recorded in July 2003.

Air Quality

Ambient Air Quality measurements taken for various parameters within the proposed

project area indicate that the values were generally within FMENV permissible

limits. The ranges for the various parameters are as follows, 1.87 – 8.20ppm for

NOx , 1.61– 9.21 ppm for SOx, , 0.10– 1.52 ppm for VOC, 2.16 – 7.33 ppm for

CO2 and <0.01– 3.51 ppm for CO.

Ambient noise levels within the study area ranged from 52.5 dB (A) at Ojobo primary

school to 93.5 dB (A) at the flare site. These values were within FMENV, DPR and

OSHA permissible exposure limits. DPR’s EGASPIN 2002 stipulates a maximum

noise level of 90dBA per 8-hours, for unprotected ears.

Vegetation

The vegetation of BCA FDP area is generally homogenous and composed mostly of

two layers of vegetation strata, namely the tree and shrub/herb layers. The tree layer is

composed mostly of pure stands of Raphia hookeri with only scattered freshwater

swamp forest tree species. The vegetation also consists of emergent tree species

SPDC Chapter Three


reaching up to 15 metres in some cases. The Vegetation cover is between 60-80%,

with patches of bushes resulting from farming activities (newly cleared farm plots,

cultivated farmlands and abandoned or fallow farm plots).

Drainage

Two major water bodies viz, Bomadi and Brass Creeks drain the study area. A few

other creeklets also aid the drainage of the area.

Regional Geology/Geomorphology

The Niger Delta complex generally consists of Cenozoic formations deposited in a

high energy regime. The region is a constructive deltaic environment and can be

divided into Continental Benin, Paralic Agbada and Pro-Delta Marine Akata

formations.

The geomorphology of the land is dominated by an almost flat terrain that is only few

meters above mean sea level. Depressions and a few minor undulations that are

perennially flooded also occur in the area.

Physico-chemistry

The soils are acidic, with mean pH values of 5.4 and 5.2. The mean concentrations of

CEC were 6.43 and 6.33 meq/100g for surface and subsurface soils respectively. The

low CEC indicates low soil fertility. Mean values for nitrogen were 0.077 and 0.065

percent for surface and subsurface soils respectively while the concentration of

phosphate ranged from 0.2 – 9.6 ppm. The distribution of these nutrients showed a

general decline with depth of the soils as the topsoil usually recorded higher values.

The concentration of heavy metals in soils was generally trace to low. There was no

significant variation in the nutrient level for both wet and dry seasons.

The fungal counts of soil samples of the BCA FDP area were low and ranged between

1.0 x 104 to 3.5 x 10

7 cfu/mg.

The count of total heterotrophic bacteria for water were found to range from 1.3x104

-

2.7 x 1010

cfu/g with a percentage hydrocabon biodegraders range of nil to 2.1% in

the dry season. The data obtained suggest that there was very little seasonal variation

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in the actual microbial counts. The predominant bacterial communities in the soil

samples of the BCA FDP area were composed of Pseudomonas sp, Proteus sp;

Micrococcus sp; Bacillus sp; Eschericha sp; Klebsiella sp.

The relatively low concentrations of hydrocarbon degrading bacteria and fungi are

indicative of the insignificant pollution status of the environment.

The results of physico-chemical analysis for the surface waters of the area reflect a

typical swamp environment. In-situ measurements of the temperatures of the surface

water within the BCA FDP area ranged from 21.8 to 33.4 0C with a mean of 29.7

0C.

Turbidity values varied between 2.1NTU and 56.0 NTU. Total dissolved Solids

varied from 30.5 to 110.8mg/l and electrical conductivity values were between 26.7

and 99.2mg/l. The pH values indicated a weak acidic range of 5.7-6.8 while

bicarbonate values ranged from 0.56 to 3.31mg/l. The chloride concentrations varied

from 26.8 to 99.2mg/l.

Chemical Oxygen Demand (COD) values ranged from 3.7mg/l to 15.3mg/l. Dissolved

Oxygen values ranged from 4.42 to 5.09mg/l while Biochemical Oxygen Demand

(BOD) values ranged from 0.85 to 1.21mg/l.

The concentrations of Na+, K

+, Ca

++, and Mg

++ ions are as follows: 2.51mg/l to

5.74mg/l; 1.87mg/l to 8.74mg/l; 4.87mg/l to 27.29mg/l and 1.83mg/l to 4.34mg/l

respectively. The heavy metal concentrations were generally low. The concentrations

of Total Hydrocarbon Content (THC) of the surface water were also low (<0.50mg/l).

Plankton Studies

The phytoplankton community of the surface water within the BCA FDP area

comprised of 32 taxa belonging to the Divisions Bacillariophyta (16 species);

Chlorophyta (6 species); Cyanophyta (3 species) and Euglenophyta (7 species). The

diatoms (Bacillariophyta) were the most prevalent followed by the Euglenoids while

Microcystis (Cyanophyta) was the most dominant blue-green species present in all the

stations in the BCA FDP area.

The zooplankton community of the surface water within the BCA FDP area was

mainly arthropods and rotifers. The arthropods were made up of cladocera,

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Conchostraca, Ostracoda and Copepoda. Bosmina longirostris and Bosminopsis

dietersi were prevalent among the cladocerans. The Ostracoda was represented by

Parastenocypris sp, Stenocypris sp and Cypridopsis. The Cyclopoids were dominant

among the copepods. The Rotifera were represented by five families and eleven

species dominated by members of the family Brachionidae.

Agriculture

Agriculture in the area is dictated by, climatic factors, soil properties and landscape

features of the coastline. The locals in the BCA FDP area are mainly subsistence

farmers and often practice mixed cropping. Crop combinations include cassava, yams,

vegetables, maize and okra. Plantain, banana and cocoyam are also cultivated in the

area. However, plantain and banana are observed to be scattered around the bushes

while cocoyam is commonly planted on dredged materials along the banks of the

creeks. Although the crops are cultivated in small scale in the area, they were

observed to be flourishing, indicating the suitability of the soil for such crops.

Fisheries

Fishing within the BCA FDP area is usually carried out using fishing gears such as fish traps,

conical baskets, hooks and lines, cast nets, sweep nets and drag nets of various mesh sizes.

Shellfishes within the area include prawns of the families Atyidal and palaemomidal and the

commercially important bivalve mollusc (Egeria paradoxa) which were mostly picked up by

divers operating from dug-out canoes along the Bomadi and Brass creeks. Fish observed in

their natural environment or bought from the fishermen operating along the creek belonged

to the orders Characiformes, Cypriniformes, Osteoglossiformes, Siluriformes and

Perciformes.

Socio-economics

The BCA FDP covers a number of communities in Bayelsa and Delta States. These include

Ojobo, in Burutu Local Government Area of Delta State and Tamogbene, Peretorugbene,

Oweigbene, Norgbene and Amabolou in Ekeremor Local Government Area in Bayelsa

State.

The estimated population of the communities within the BCA FDP area is 37,468

(1991 population census) people. Some of the communities within the BCA FDP area

studied include Ojobo (7,204 people), Peretorugbene (9,037 people), Tamogbene (375

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people), Amabolu (4,778 people), Norgbene (2,401 people) and Ekeremor (10,393

people).

The literacy level in the study area is relatively high especially in the two main communities

Ojobo and Peretorugbene. There are a total of 11 primary and 5 secondary schools, which

are evenly spread within the area.

The two major BCA landlord communities, Peretorugbene and Ojobo, are

homogeneously Ijaw, a major ethnic group in the Niger Delta region.

The locals are predominantly fishermen, a small fraction however engage in crop farming.

About 27% of residents within the BCA FDP area earn over N2000 weekly from fishing

while 42% earn less than N500. Over 30% of residents within the BCA FDP area earn less

than N5000 weekly from other sources including farming.

Health Status

Health facilities were generally lacking in the area, even where health centres existed,

they lacked equipment and drugs. Most residents in the area depend on the patent

medicine store dealers “doctors” for medical attention.

History and physical examination of the sampled population in the communities

surveyed revealed certain morbidity characteristics. They include, fever/frequent

headache, Blurred vision, Diarrhoea and vomiting, Skin rashes, Marked weight loss,

Cough and Catarrh. From interviews conducted and records from health centers, there

was no reported case of HIV/AIDS in the area.

Potential Impact Assessment

The assessment of the degree of alteration to natural conditions due to the project

activities were carried out using the modified Leopold interaction matrix. The overall

potential negative impacts of the project activities on the environment are minimal.

Site preparation, drilling, dredging and flowline laying are some activities, which

would adversely affect the environment.

However, these negative impacts will be minimal, localised and short-term

particularly given the fact that the adverse impacts will be properly mitigated with the

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strict implementation of the Environmental Management Plan developed for the

proposed project. Consequently, the long-term beneficial impact of the proposed

project makes it more beneficial than adverse.

MITIGATION AND AMELIORATIVE MEASURES

To ensure the successful execution of the BCA FDP project, SPDC shall apply the

following measures:

Ensuring that vegetation cutting / clearing activities are reduced to the barest

minimum. The cutting of vegetation outside the designated areas and creation of

access routes into the forest shall be prohibited.

Effective journey management shall be applied (transport of heavy duty equipment

and pipes during peak traffic period shall be avoided)

HSE training and job hazard analysis shall be conducted to ensure that all staff

observes safety rules at work places.

SPDC shall identify the locations of burial sites and shrines to avoid damage during

construction

Exposure to high noise equipment shall be restricted to the recommended 8-hour a

day limit

SPDC shall maintain fuel combustion engines at optimal operating conditions to

reduce emissions of exhaust gases.

Routine inspection of wellheads and other facility shall be maintained to ensure

facility integrity.

SPDC shall regularly conduct monitoring of the project environment using an

environmental monitoring plan.

Excavation and other activities that may result in the alteration of the landscape and

condition of the land cover shall be limited.

SPDC shall manage wastes generated in accordance with regulatory requirements and

standard practices.

SPDC shall keep to the operational lifespan of the project.

Appropriate warning signs shall be used to alert residents of the presence of

machines/equipment at abandonment and decommissioning.

SPDC shall embark on community development programmes in line with the desires

and needs of the people.

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SPDC shall activate her oil spill contingency plans to minimize impacts of oil spills

and leaks on ponds, creeks and rivers.

Environmental Management Plan

The Environmental Management Plan (EMP) for the proposed BCA FDP incorporates

various mitigation measures to ensure that adverse impacts associated with the

development of the BCA field are reduced to As Low As Reasonably Practicable

(ALARP) levels. The EMP addresses waste management, environmental audit and

environmental monitoring programmes of the BCA FDP.

Waste management plan for the BCA FDP is targeted primarily at waste

minimisation, waste reuse and recycling such as, reuse and recycling of drilling mud.

The plan has taken into consideration, waste elimination by designing out unnecessary

waste generating modules and incorporating waste reduction opportunities such as

drilling of slim holes, use of slim width dredging, clearing of slim Right of Ways

(ROWs) and cluster drilling. Processes already exist to measure and record quantity of

waste generated.

Environmental audit will be conducted on a regular basis for all operations facilities

throughout the life span of the BCA FDP project.

The Environmental Monitoring Programmes for the proposed project, which shall

cover environmental components and discharge types, shall comply with

DPR/FMENV regulatory requirements.

Conclusion

The EIA of the BCA FDP indicates that the environmental components that are likely to be

adversely impacted are vegetation, water quality, fisheries /wildlife, macrophytes and

benthos. There is also the likelihood of direct impact on human population within the project

area in terms of health and socio-economic well being.

SPDC Chapter Three


However, this EIA report has developed a well articulated Environmental Management plan

to reduce the adverse impacts of the project on the environment to as low as reasonably

possible levels.

SPDC Chapter Three


CHAPTER ONE

1.0 INTRODUCTION

1.1 General

Shell Petroleum Development Company of Nigeria Limited (SPDC) proposes to further

develop the Benisede Catchment Area (BCA) Field. The field development is aimed at

boosting oil output and to also test neighbouring prospects. The Benisede Catchment Area

(BCA) Field Development Plan (FDP) phase 2 covers the lifecycle re-development plan of

the Benisede Catchment Area i.e. Benisede field and prospects, as well as Akono, Opomoyo,

Osuopele and Orubou fields. The plan presents a base case development scenario targeting

117.2 MMstb of reserves through the drilling of about 11 wells.

1.2 The Proponent

Shell Petroleum Development Company of Nigeria Limited (SPDC) is a major Oil &

Gas exploration and production (E & P) Company in Nigeria. It operates a joint

Venture Partnership with Nigerian National Petroleum Corporation (NNPC), ELF

Petroleum Nigeria Ltd (EPNL) and Nigerian Agip Oil Company (NAOC). The

partnership participation are 55%, 30%, 10% and 5% for NNPC, SPDC, ELF and

NAOC, respectively.

SPDC first discovered oil in commercial quantities in Nigeria in 1956, although it had

been operating in Nigeria since 1938. The company finally adopted the name Shell

Petroleum Development Company of Nigeria Limited in 1978 after previously

changing its name from Shell D’ Arcy to Shell-BP.

The company has 92 producing oil fields. These fields, including the BCA Field, are

located in the Sedimentary basin of the Niger Delta region with a production potential

of over one million barrels of oil per day (about 50% of Nigeria’s Oil production

capacity), the SPDC is the largest Oil exploration and Production company in Nigeria.

1.3 Background Information

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The BCA field was discovered in 1973 with 17 hydrocarbon-bearing reservoirs and

the only flowstation in the area was commissioned in 1976. Currently, 20 wells are

tied into the flowstation producing from 3 fields. Two other adjacent fields, Akono

and Opomoyo, were discovered and tied into the Benisede station in 1996 to make up

the Benisede Catchment Area (BCA). Crude evacuation from the field is via the 16”

South Forcados Trunkline connecting to the Trans Ramos Trunkline, which

terminates at the Forcados Terminal.

The field covers an area of about 16 sq. km. The estimated land-take within Benisede

field is 301.49 Ha and is accessible by air and water. A flight journey from Industrial

Area (where all SPDC transportation facilities e.g. boats, helicopters, cars, trucks, etc.

are based) to Benisede takes about 28 minutes while a boat takes about 3 hrs. There is

a helipad equipped with lights, and a jetty that serves the Flowstation, which has a

capacity of 60,000bpd and a total of 24 wells (22 in Benisede, 1 in Akono and 1 in

Opomoyo) out of which, 20 are producing (i.e. 18 in Benisede and 1 each in Akono

and Opomoyo) with all the flowlines buried.

Recent studies show an undeveloped oil reserve, which stands at about 63% of

remaining reserves. Consequently, the plan to redevelop the BCA field is aimed at

exploiting these undeveloped reserves.

SPDC has carried out this EIA in order to comply with all relevant statutory

requirements as well as ensure that its operations in respect of the BCA FDP are

within the principles of sustainable development. Consequently, the EIA process has

systematically evaluated the environmental consequences of the proposed project and

also proffered mitigation measures for adverse impacts identified. This report will

therefore serve as the basis for communication to obtain relevant approvals from

regulatory agencies i.e. FMENV and DPR, and also to satisfy public information

needs on the BCA FDP project.

1.4 EIA Objectives

The objectives of the EIA study include the following:

to determine the baseline ecological conditions of the study area;

to determine the environmental sensitivities prevalent in the area;

SPDC Chapter Three


to identify, evaluate, and predict the impact of the project on the ecological,

socio-economic and cultural settings with adequate interfacing and project

interaction;

to identify health hazards that may result from the different phases of the

project and evaluate local population exposure to these hazards.

to develop control strategies with a view to mitigating and ameliorating

significant impacts that the projects would have on the totality of measurable

environmental characteristics;

to develop a cost effective Environmental Management Plan (EMP) for the

impacts identified.

1.5 EIA Methodology

The EIA study of the proposed Benisede Catchment Area FDP was carried out in

accordance with the Federal Ministry of Environment (FMENV) Procedural and

Sectoral Guidelines 1995, the Department of Petroleum Resources (DPR) EGASPIN,

2002 and the new SPDC EIA Manual. The study involved a blend of a

multidisciplinary team and standard methods from pure science, engineering, social

and health sciences in order to obtain basic data for impact identification and

establishment of mitigation and amelioration measures. The study generally involved

desktop studies, field research, consultation, impact assessment and proffering of

mitigation measures and development of an environmental management plan (EMP).

Desktop Studies

Desktop studies were undertaken to acquire information on climate, geology, soil,

vegetation, socio-economics, and other environmental components of the proposed

Benisede Catchment Area FDP. The materials consulted include textbooks, articles,

and previous study reports on the proposed project area e.g. the Benisede Catchment

Area FDP Baseline Study Report (Dec., 2002), charts, articles, and maps.

Field Research

A field research was used to harmonize and verify information gathered from desktop

studies and also fill data gaps identified. The fieldwork was carried out in line with

the FMENV Procedural Guidelines (1995) and DPR Guidelines and Standards for

Petroleum Industry in Nigeria (Draft Revised Edition 2002) whilst maintaining SPDC

SPDC Chapter Three


HSE and QA/QC standards. The data gathered from the field investigation were used

in determining relevant baseline ecological, socio-economic and health conditions of

the proposed project area.

Consultation

Consultation was carried out with the proposed project stakeholders (FMENV, Delta

and Bayelsa States Ministry of Environment, communities and NGOs). Some of these

were consulted during the scoping stage, prior to the start of the field campaign. This

was done to ensure that the views and opinions of all stakeholders regarding the

proposed project and its associated and potential impacts are integrated into the EIA.

Potential Impact Assessment and Mitigation

A combination of modified Leopold matrix and the checklist methods were adopted in

assessing the potential and associated impacts of the proposed project. The FMENV

EIA Sectoral Guidelines for Oil and Gas Industry Projects as well as the

environmental baseline and socio-economic status of the project area and other

references were used to identify and evaluate the potential and associated impacts of

the proposed project and also to proffer appropriate mitigation measures. This was

carried out in an interactive manner as shown in Figure 1.1

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Recommendations on

base resource requirement,

availability of manpower / technology and

public acceptance

Figure 1.1: Assessment Pattern

Professional judgment, knowledge of the ecosystem where the project will be located,

experience on similar projects and consensus of opinions of experts/consultants were

used in determining the appropriate impact mitigation measures/ EMP.

1.6 Legal and Administrative Framework for EIA in Nigeria

The EIA of the proposed BCA FDP was carried out in accordance with regulations,

guidelines and standards of the Federal Ministry of Environment and the Department

of Petroleum Resources, State legislations on the environment and all other applicable

National legislations, and International Agreement and Convention to which Nigeria

is a signatory. The EIA is also in conformity with all SPDC HSE policies.

1.6.1 Environmental Impact Assessment (EIA) Act

Avoidance Mitigation Monitoring & Follow up

Scoping & identifying Issues

Predicting Impacts

Evaluating Impact Significance

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The Environmental Impact Assessment (EIA) Act (Act No. 86 of 1992) makes EIA

mandatory for all new major public and private projects in Nigeria. The EIA Act sets

out to:

(i) Consider the likely impacts, and the extent of these impacts on the

environment before embarking on any project or activity.

(ii) Promote the implementation of appropriate policy in all federal lands

consistent with all laws and decision-making processes through which the goal of this

Act may be realized.

(iii) Encourage the development of procedures for information exchange, notification

and consultation between organizations and persons when the proposed activities are

likely to have significant environmental effects on boundary or trans-state or on the

environment of bordering towns and villages

The EIA Act gives specific powers to the Federal Environmental Protection Agency,

FEPA (now FMENV) to facilitate environmental assessment of projects. In

September 1995, FEPA published the EIA Sectoral Guidelines for Oil and Gas

Industry projects. The guidelines are intended to assist in the proper and detailed

execution of EIA of oil and gas projects in consonance with EIA Act of 1992.

1.6.2 Petroleum Act 1969, Section 8(III)

The Petroleum Act of 1969 makes provision for the prevention of pollution of

watercourses and the atmosphere during petroleum operations.

1.6.3 Oil Pipeline Act And Oil & Gas Pipelines Regulations 1958 (Amended 1995)

These Acts regulate the right to establish, maintain and operate oil pipelines and

ancillary facilities in Nigeria. The Acts require that applications for permit to survey

an oil pipeline route be submitted to the Minister for Petroleum Resources. Upon

completion of the survey, the holder of a permit to survey may apply to the Minister

of Petroleum Resources for an Oil Pipeline License, subject to the payment of the

prescribed fees. The license shall entitle the holder to enter and take possession or use

a strip of land as may be specified in the license and thereafter to construct, maintain

and operate the pipeline and ancillary facilities.

Also, the Oil and Gas Pipelines Regulations of 1995 provides detailed regulations for

the design, construction and inspection of oil and effluent water disposal pipelines in

addition to guidelines for the design and construction of oil transmission and

distribution pipelines. It further provides for procedures for upgrading pipelines or

changing of substances transmitted by the pipeline and for the discontinued use or

SPDC Chapter Three


abandonment of the pipeline system. The Act makes it mandatory for a holder of a

pipeline license to pay compensation to any person that suffers damage as a result of

any ancillary installation.

The Oil Pipeline Act and the Oil and Gas Pipeline Regulations of 1995 thus, do not

require project proponents to conduct an EIA, but only to undertake a route survey.

However, integrating the requirements of the Act and Regulations into the framework

of the EIA is the most expedient approach to ensuring that all the provisions contained

in these statutes are fully complied with.

1.6.4 Mineral Oils Safety Regulations 1963 (Amended 1997)

These regulations provide that a licensee or lessee shall:

• Ensure that no pipeline is put into operation without the approval of the

Director of Petroleum Resources;

• Make sure that the right of way of every pipeline is free of overgrowth and

weeds in order to allow for easy access for conducting operational tests, other

maintenance works and for prompt detection of leakages;

• Carry out cathodic protection potential survey on all buried pipelines at

intervals of not more than 2 years to ensure that every section of the protected

line attains a negative potential of not less than 850mV with respect to

copper/copper sulphate reference electrode;

• Provide clear, comprehensive, safe and practical operational procedures and

guidelines for the workforce;

• Develop and maintain contingency procedures and measures for the safety of

personnel and equipment in an emergency;

• Maintain a documented system setting out the responsibilities of the

competent persons involved in onshore and offshore operations, their mutual

relations and lines of reporting and communications;

• Ensure that every personal protective equipment is judiciously used and

maintained in serviceable condition at all times;

• Ensure that every pressure vessel and its fittings in use in an oilfield operation

shall be regularly examined in accordance with the manufacturer’s

recommendations and good oilfield practices;

• Ensure that every pressure vessel equipment and associated piping used in

oilfield installations meet the National Association of Corrosion Engineers

(NACE) or other recognized equivalent standards for monitoring and

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controlling corrosion, with respect to their design, construction, routine

inspection, testing and maintenance;

• Ensure that every crane and hoist equipment to be used for work is operated

by a trained person who shall always ensure that the equipment is inspected

and maintained as recommended by their manufacturers; and

• Safely handle all diving operations and the activities of his diving contractors,

to ensure that, as far as is reasonably practicable, the activities are carried out

in accordance with all relevant local legislation codes, standards and other

international safe diving practices

1.6.5 National Environmental Protection (Effluent Limitations) Regulation

(S.1.8) 1991

This regulation makes it mandatory for industries generating wastes to install anti-

pollution and pollution abatement equipment on site. The regulation is specific to

each category of waste generating facility with respect to limitations of solid and

liquid discharges or gaseous emissions into the ecosystem. Appropriate penalties for

contravention are also specified in the regulation.

1.6.6 National Environmental Protection Regulation (S.I.9) 1991

The National Environmental Protection (Pollution Abatement in Industries

Producing Waste) Regulation of 1991 regulates the release of toxic substances,

requirement for pollution monitoring unit, machinery for combating pollution and

contingency plan by industries. It also provides that industries producing wastes

should submit lists and details of chemicals used by such industries to FMENV as

well as permissible limits of discharge into public drains. It details protection of

workers, requirements for environmental audit and penalty for contravention.

1.6.7 National Environmental Protection (Management of Solid Hazardous Wastes

Regulation (S.1.15) 1991

This regulation spells out the requirements for groundwater protection, surface

impoundment, land treatment, waste piles, landfills, incinerators, etc. It also describes

the hazardous chemical products and dangerous waste constituents.

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1.6.8 EIA Sectoral Guidelines of the Federal Ministry of Environment (FMENV)

Federal Environmental Protection Agency (FEPA) now Federal Ministry of

Environment (FMENV), was established by Act 58 of 1988 to monitor and prevent

the pollution of the environment following the Koko toxic wastes dump incident. This

empowered FEPA to prepare Environmental Guidelines and Standards as instruments

for prevention of environmental pollution. This Act also gives specific powers to

FEPA/FMENV to facilitate environmental assessment of projects.

In addition, FEPA regulations S.1.8, S.1.9 and S.1.15 of 1991 provided guidelines and

standards for the following:

- Solid and Hazardous waste management

- Effluent limitations

- Pollution abatement in industries generating wastes.

In September 1995, FEPA published EIA Sectoral guidelines for projects in the Oil

and Gas industries in Nigeria. The guidelines are intended to assist in the proper and

detailed execution of EIA Studies of the oil and gas projects in compliance with the

EIA Act of 1992. The FMENV EIA Management process is shown in Fig. 1.2.

PROPONENT

FEASIBILITY STUDY OR PROJECT PROPOSAL

FMENV EIA SECRETARIAT

INITIAL ENVIRONMENTAL EVALUATION

MANDATORY

PROJECTS OTHERS CLASSIFIED PROJECTS EXCLUDED

PROJECTS

PRELIMINARY ASSESSMENT SCREENING

SCOPING

DRAFT EIA REPORT

NO EIA

REQUIR

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Figure 1.2: FMENV EIA Management Procedure

1.6.9 DPR’s Requirements for EIA

The Department of Petroleum Resources (DPR) was established by the Petroleum Act

of 1969 and amended in section 191 of the NNPC Act of 1979. This Act empowers

DPR to ensure that Petroleum Industry operators in Nigeria do not degrade the

environment in the course of their operations. They also enforce the clean-up and

restoration of Oil spills and impacted environment to acceptable levels, as well as

control new projects that may adversely impact the environment. Thus the power of

supervision over the entire operations of oil industries is vested on DPR.

One of the principal regulations that mandates DPR to issue licenses/permits and

establish guidelines, standards and procedures for environmental controls is Section

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8(1) b (iii) which empowers the Minister of Petroleum Resources to make regulations

for the conservation of petroleum resources and prevention of pollution of water

courses and atmosphere.

Consequently, DPR requires by legislation, that holders of exploration, prospecting,

refining, transportation and marketing licenses of petroleum resources take/adopt

practical precautions and all steps practicable to prevent pollution, and cause as little

damage as possible to the environment in their areas of operation. Therefore, the use

of Environmental Impact Assessment as an environmental management tool is

mandatory and is adopted by DPR as an additional enforcement strategy. Rules and

regulations guiding the activities in the petroleum industry in Nigeria are specified in

the Environmental Guidelines and Standards for the Petroleum Industry in Nigeria,

EGASPIN 2002, issued by DPR.

The DPR EIA Management process is shown in Fig. 1.3.

SPONSOR

Prepares and submits IEE

to DPR

DPR screens IEE with

operator

Project proceeds

(with monitoring)

* 30 days

NO

SC

RE

EN

ING

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ImpactSignificant?

Figure 1.3: DPR Flowchart for the EIA Process

1.6.10 Forestry Law CAP 51, 1994

The Forestry Act 1958 which was amended as the Forestry Law CAP 51, (1994)

prohibits any act that may lead to the destruction of or cause injury to any forest

produce, forest growth or forestry property in Nigeria. The law prescribes the

administrative framework for the management, utilization and protection of forestry

resources in Nigeria, which is applicable to the mangrove, and other forests of the

Niger Delta.

1.6.11 Land Use Act of 1978

DPR constitutes Panel to

scope full EIA

Operator carries out EIA

and submits EIA/EIS Draft

to DPR

DPR reviews draft and

requests for final EIA/EIS

to be developed

Operator submits Final EIS

to DPR

* 21 days

* 7 days

END

YES

SPDC Chapter Three


The land-use Act of 1978 states that “… it is also in the public interest that the rights

of all Nigerians to use and enjoy land in Nigeria in sufficient quality … to enable

them to provide for the sustenance of themselves and their families should be assured,

protected and preserved”.

1.6.12 Delta and Bayelsa States Ministries of Environment

The States Ministries of Environment in Delta and Bayelsa States have the

responsibility of environmental protection within their States. The applicable State

regulations (e.g. DELSEPA Edict No. 5 of 1997) have been taken into cognizance as

part of the proposed project. Some of the functions of the State Ministries of

Environment include:

(i) liaising with the Federal Ministry of Environment, FMENV (formerly

FEPA) to achieve the National policy on Environment,

(ii) co-operating with FMENV and other National Directorates/Agencies in

the performance of environmental functions including environmental

education / awareness to the citizenry,

(iii) responsibility for monitoring waste management standards,

(iv) responsibility for general environmental matters in the States, and

(v) monitoring the implementation of EIAs and other environmental studies

for all development projects in the States.

1.6.13 SPDC HSE Policy

Shell Petroleum Development Company of Nigeria Ltd (SPDC) in her Health, Safety

and Environment (HSE) Policy states that SPDC:

(i) Has a systematic approach to HSE management designed to ensure

compliance with the laws and to achieve continuous performance

improvement,

(ii) Sets targets for improvement and measures, appraises and reports

performance,

(iii) Requires contractors to manage HSE in line with this policy,

SPDC Chapter Three


(iv) Requires joint venture under its operational control to apply this policy and

use its influence to promote it in its other ventures,

(v) Includes HSE performance in its appraisal of all staff and rewards

accordingly.

All operations/activities in the BCA FDP shall be carried out in accordance with the

above-stated HSE policy objectives.

1.6.14 Other National and International legislation and Conventions

Other National and international legislation and conventions relevant to the Benisede

Catchment Area FDP are summarized in Appendix IV.

1.7 Structure of the Report

This EIA report is presented in nine chapters. Chapter one is an introduction stating

the background information about the project and the proponent and the

legal/administrative framework for EIA in Nigeria. The second chapter discusses the

project justification and presents the need / value and the envisaged sustainability of

the project as well as the project development options considered. Chapter three

contains a concise description of the proposed project activities including project

scope of work, design philosophy, engineering/detailed design, project management

and operations philosophies and the project execution schedule. The fourth chapter

describes the existing biophysical and socio-economic baseline status of the project

area as well as the health status of the residents.

Chapter five presents consultation with identified stakeholders including host

communities and regulators. The potential and associated impacts of the proposed

BCA FDP project is presented in chapter six while chapter seven proffers mitigation

and enhancement measures and alternatives for the identified adverse and beneficial

impacts. Chapter eight describes the environmental management and community

development plans that SPDC proposes to adopt during implementation of the

proposed BCA FDP project. Chapter nine concludes the EIA report while presenting

the key findings of the study.

1.8 Declaration

SPDC Chapter Three


Shell Petroleum Development Company Ltd (SPDC) hereby declares that the BCA

FDP project will be executed in compliance with the above stated legal and

institutional frameworks. SPDC will therefore take responsibility to mitigate the

identified impacts from the BCA FDP project.

SPDC Chapter Three


CHAPTER TWO

2.0 PROJECT JUSTIFICATION

2.1 General

Benisede Catchment Area (BCA) comprises Benisede field and its satellite fields and

prospects (i.e. Akono, Opomoyo, Osuopele and Orubou). Crude oil production

commenced at Benisede Field in May 1976 with a cumulative production of 227

MMstb as at 2002. Peak rate was 47,850 bopd at 7% watercut in 1984. This declined

to about 28 Mbopd at 46% watercut by mid 1998. Currently BCA produces about 34

Mbopd at 40% BSW. Only 48% of this production is from Benisede while Opomoyo,

a small satellite field, contributes 40%. Latest estimate of Undeveloped Reserve was

355.4 MMstb and 63 % of remaining reserves is considered yet undeveloped.

2.2 Project Objectives

The objectives of the BCA FDP Project include;

to generate a life-cycle field development plan for the Benisede Catchment

Area (BCA),

develop the remaining reserves in these fields (Benisede, Akono, Opomoyo,

Orubou and Osuopele) and

test neighbouring exploration prospects.

This project also leverages on the Southern Swamp Associated Gas Gathering (SS-

AGG) project building new oil and gas facility and providing the additional ullage

required for further field development activities. In the short-term, the existing

flowstation will be debottlenecked prior to its upgrade. Hence, this plan is aligned

with SPDC’s corporate sustainable development objectives through the gas-gathering

project and the adoption of new EIA process.

2.3 Need for the BCA FDP Project Phase 2

SPDC’s intention to further develop the BCA is based on the need to increase the

hydrocarbon reserves of the country. The wells currently in the BCA field have long

been in production. There is the need to upgrade the facilities so as to optimize as well

as increase the hydrocarbon reserves of the BCA field. This will contribute to increase

SPDC Chapter Three


in the total national hydrocarbon reserves and export earnings in a cost-effective and

environmentally sound manner.

2.4 Benefits of the BCA FDP Project Phase 2

On completion, the benefits of the BCA FDP Project are numerous and cannot be

over-emphasized. Some of the benefits of the BCA FDP Project will include:

(i) Increase Nigerian Oil production and therefore provide a significant contribution

to overall Nigerian oil level and hence boost the Nigerian economy.

(ii) Improve the standard of living of Nigerians and therefore enhance socio-

economic development of Nigeria.

(iii) Ensure gainful employment of Nigerians.

(iv) The BCA FDP Project will reduce gas flaring and therefore contribute to

environmental conservation.

2.5 Envisaged sustainability of the BCA FDP Project Phase 2

The key challenge of sustainable development for this FDP phase 2 project is to demonstrate

its economic contribution, satisfy the growth for energy demand, whilst also

safeguarding the environment and acting in a socially responsible manner. The

sustainable development philosophy of minimizing land-take, cost and the impact

on the environment has been adopted for this development project. The set goal is,

“meeting the needs of the present without compromising the ability of future

generations to meet their own needs”.

2.5.1 SOCIAL SUSTAINABILITY

The social sustainability of the BCA FDP Phase 2 Project shall emanate from the

extensive consultations, which have been held with host communities. These

consultations, some of which have been sustained are expected to create a good

working relationship between SPDC and the communities.

2.5.2 ENVIRONMENTAL SUSTAINABILITY

The BCA FDP Phase 2 Project shall be environmentally sustainable because of the adoption

of SPDC HSE policy and the improved EIA process for the project. Incorporating

the findings and recommendations of this EIA and subsequent implementation of

SPDC Chapter Three


the Environmental Management Plan for every phase of the BCA FDP project will

ensure the required environmental sustainability.

2.5.3 ECONOMIC SUSTAINABILITY

The BCA FDP Phase 2 Project shall be economically sustainable because of the huge

hydrocarbon deposits (tabulated in Chapter 3.0) to be exploited in the BCA field.

2.6 Project Alternatives

Three (3) possible integrated development alternatives/scenarios were identified:

Scenario 1: No Action/Do nothing

Scenario 2: Development activity with upgraded 90 Mbpd facility

Scenario 3: Development activity with new 90 Mbpd facility

Scenario 1: No Action/Do Nothing option

This option involves the operation of the BCA field as is currently operated without

any further development. This option was dismissed because it will not achieve the

above-stated needs and benefits of the project.

Scenario 2 (Brown Field): Development activity with upgraded 90 Mbpd facility

This scenario considers the various ways of upgrading and increasing the capacity of

the existing flowstation as previously discussed. Specific options considered include:

a.) debottlenecking to 90Mpd,

b.) Debottlenecking to 90 Mbpd and further capacity extension via the use of EPFs of

various sizes and acquisition arrangement,

c.) Debottlenecking to 90 Mbpd and installing a 30Mbpd third train.

d.) Upgrading to 90 Mpd and installing gas gathering equipment through SFAGG.

This scenario can deliver production acceleration by allowing new wells to be drilled

earlier than the SFAGG (except for option d). They also allow flexibility for handling

production upsides and a possibly earlier hook-up of exploration upsides. EPFs can be

de-commissioned at periods of low peak and used elsewhere in the district.

SPDC Chapter Three


Besides the reasons previously stated, these scenarios are not viable for long term

application given the absence of oil and gas integrated operations (except for option

d) and the need for 24 hr manning. Hence, they are regarded as unrealistic for either

being opposed to SPDC's new operating philosophy or the long-term sustainable

development objective. For these reasons and the previous technical conclusions

reached by the SFAGG team, no further evaluation of these scenarios was done.

Scenario 3 (Green Field): Development activity with new 90 Mbpd facility

Scenario 3 is completely aligned with the firm and committed SFAGG project to

build a 90 Mbpd integrated oil and gas Mobile Production Facility.

The decision to build a 90 Mbpd flowstation was reached by the SFAGG team

following preliminary forecasts and economic runs comparing the 90 Mbpd. The

strategy therefore, in the event of unexpected upsides in reserves or exploration gains,

is to optimise ullage utilisation through water cut management.

Generally, exploration gains will be deferred till ullage is created from natural

production decline.

The main risk presented to these scenarios is the impact of possible delays in the SS-

AGG project and the resultant project value erosion.

Scenario 3 is the preferred alternative given its economic advantages and environmental

implications. This Green Field alternative gives opportunity for an integrated oil

and gas facility, and thus incorporates SPDC’s new operational philosophy of

integrated oil and gas operations. The scenario is also in line with the Federal

Government’s flares down policy. Scenario 3 is therefore an environment friendly

alternative.

SPDC Chapter Three


CHAPTER THREE

3.0 PROJECT DESCRIPTION

3.1 General

This chapter presents the technical details of the proposed Benisede Catchment Area

(BCA) Field Development Phase 2 Project. This includes the proposed BCA

project location, project activities, design philosophy, wellhead design, drilling

operations, mud programmes, etc and the overall project schedule.

3.2 Project Scope

The scope of the proposed Benisede Catchment Area FDP project would cover the

following principal activities:

Collection and Transportation of materials;

Land Acquisition (about 301.49 Hectares);

Drilling of 11 wells;

Dredging;

Laying about 50km of flowlines to the flowstation;

Flowline and jacket construction;

Clearing of the Right of Way;

Purchase of the pipes;

Coating of pipes;

Welding and Laying of pipes;

Radiography of welded joints;

Excavation/Back filling;

3.3 Project Location

The Benisede Field is located in the Swamp and Fresh-Water region of OMLs 35 and

46 (Fig. 3.0), about 65 km South-South-West of Warri (Map 1, Appendix I). It is

situated between latitudes 112500N and 113500N and longitudes 362250 and

362750E and is located within two local government areas; Burutu in Delta and

Opurumor West Local Government Area in Bayelsa State.

SPDC Chapter Three


Fig 3.0: Benisede Catchment Area

3.4 The proposed project Overview

The Benisede Catchment Area FDP Phase 2 project covers the lifecycle re-

development plan of the Benisede Catchment Area (BCA) i.e. Benisede field and

prospects, Akono, Opomoyo, Osuopele and Orubou fields (Fig. 3.1). A major drilling

campaign will be carried out in Benisede Catchment Area. Eleven (11) new wells (8

in Benisede and 2 in Akono and 1 in Opomoyo) will be drilled and this will be made

up of 9 horizontal wells and 2 conventional wells. Also in the plan is the laying of

about 50 km of oil flowlines. In order to realise a gaslift gain (license period) of about

15.7 MMstb, a 20 km long 6" HP line will be laid from the Benisede flowstation to

the Tunu-CPF when completed. Some 33 km of lift gas distribution lines will also be

laid between the flowstation and wells requiring lift-gas in Benisede field.

NUN RIVER

DIEBU CR.

N. APOI

OKUBIE

TEBIDABA

EA

PENNINGTON

MIDDLETON

OWOPELE

ODON

OGBOTOBO

KANBO

OZORO

OWEH

DELTA S. SAGHARA

MEJI AFREMO MEFA

OKAN WARRI RIVER

AGHIGHO UPOMANI

EJA

AGBAYA

TUNU

ERIEMU

OPUKUSHI

BENISEDE

AFIESERE

UTOROGU ORONI

OTUMARA

ESCRAVOS

FORCADOS-YOKRI

EGWA W.

ODIDI

EGWA E. BATAN

AJUJU

RAPELE JONES CR.

UGHELLI E

EVWRENI OSIOKA

UGHELLI W

34

42 44

81 79

46

35

36

31

30

45

KOKRI

ANGALALEI

OKPOKONOU

SEIBOU

OML 35:

Benisede + Prospects

Akono

Opomoyo

Orubou

SPDC Chapter Three


Fig. 3.1: Benisede Prospects

The BCA FDP is closely aligned to the SS-AGG project i.e. building new oil and gas

processing and the additional crude processing ullage required for the new

development. An upgrade of the existing 60Mbpd flowstation to a 90 Mbpd concrete

badge mounted Flowstation is planned for commissioning in late 2008.

3.5 Surface Locations

3.5.1 Benisede Field

The wells in Benisede field will be drilled from four surface locations consisting of

two new locations and two location extensions. One well (S1S7T3C*) will be drilled

as a stand-alone from a new location. This is because the appraisal objectives of the

well require it to be drilled as a fault scooper and no existing well location is

optimally placed to allow this. The second stand-alone well, Bens R6-H, (see Fig. 3.2)

will be drilled from the extension of Benisede-11 location.

BENISEDE D PROSPECT

BENISEDE G PROSPECT

BENISEDE C PROSPECT

BENISEDE E PROSPECT

OPOMOYO FIELD

AKONO FIELD

BENISEDE FIELD

OML 46 OML 35

OSUOPELE SW FIELD

OSUOPELE FIELD

SPDC Chapter Three


Fig. 3.2: Completion Diagram for Benisede-H

24 ” refusal

6” hole

9-5/8”

Proposed Opom -H (With 5-/12”SL & ECP) Proposed Bens -H (With 4-1/2” & OHGP)

24”

13-3/8”

Shale layer ,

9-5/8”

blank pipe

.

Proposed Bens -H (With 4-1/2” SL/WWS) Proposed BensR6-H (With 3-1/2” WWS)

8-1/2” hole

24 ” refusal

6” hole

9-5/8”

24 ” refusal

6” hole

9-5/8”

.…………... ..……………...

.…………….. .……………..

SPDC Chapter Three

EIA of Benisede Catchment Area Phase II Field Development Plan June, 2005 Page 57 of 253

The remaining two locations will be clusters. One of the cluster locations will be

constructed from a new area and will have three wells (S7H9, S1H and T3H). The

other cluster location will be an extension of Benisede-3 location and will have three

wells (S7C, R7H, S2H2*).

Thus the Benisede well construction operation will require the dredging of some 2.32

hectares (excluding access routes) of land.

3.5.2 Akono Field

Two horizontal wells in Akono field will be drilled from a single surface location,

which will be an extension of the existing Akono-1 location. This would require the

dredging of about 1.0 hectare of land.

3.5.3 Opomoyo Field

A single horizontal well in Opomoyo field will be drilled from a new surface

location. Drilling from the existing Opomoyo-1 location was ruled out because it

would require an extremely tortuous wellpath given the reservoir extension appraisal

objectives of the well. The surface location would require the dredging of about 0.7

hectare of land.

3.6 Proposed Project Design Philosophy

A nodal development philosophy has been applied in developing a full lifecycle FDP

for the matured Benisede field and neighbouring fields. The strategy adopted

leverages on the firm and committed Sustainable Development programme involving

the building of gas gathering facilities, a new oil and gas processing facility and

additional ullage capacity via the SS-AGG project.

This FDP includes notional future development activities closely tied to additional

ullage availability created by the SS-AGG project. Gas lift gains are to be re-

appraised towards the currently estimated ETT. An HP line is to be laid from the

Tunu CPF if considered still viable and providing that compression ullage will be

available as presently forecasted.

SPDC Chapter Three


Recently evaluated exploration prospects will be tested via the drilling of exploration

wells. Hence, this FDP will be updated following the interpretation of these

wells.

A further FDP update will be required to generate Gas development activities. This

will however depend on new commercial opportunities in the Gas market.

3.7 Engineering and Detailed Design

3.7.1 Applicable Standards and Codes

All Design and Engineering Practice (DEP) and SPDC standards and codes,

applicable to various aspects of oil and gas projects such as mechanical, process,

corrosion, pipeline, flowlines, and HSE shall be followed in the Benisede

Catchment Area FDP project. In general, the project will be designed in

accordance with:

a) Relevant Nigerian Government Legislation;

b) Project Specification and Concept;

c) SPDC Specification and Standard;

d) Design and Engineering Practices (DEPs),

e) HSE Manuals;

f) Procedure Guide for the Construction and Maintenance of Fixed Drilling

platforms, Department of Petroleum Resources, Nigeria.

g) “Guidelines and Procedure of Oil and Gas Pipelines and their Ancillary

Facilities”, Department of Petroleum Resources, Nigeria.

h) “Procedure Guide for the Determination of the Quantity and Quality of Crude

oil and Petroleum Products at Custody Transfer Points”, Nigerian Ministry of

Petroleum and Mineral Resources.

i) API RP 2A-WSD: “Recommended Practices for Planning, Designing and

Construction Fixed Drilling Platforms – Working Stress Design”, 20th

edition;

July, 1993.

j) API Spec 2B “Fabrication for Fabricated Structural Steel Pipe”

k) API RP 2G “Recommended Practice for Production Facilities on Drilling

Structure”

SPDC Chapter Three


l) APE Spec 2H “Specification for Carbon Manganese Steel Plate for Drilling

Tubular Joints”

m) API 5L “Specification for Line Pipe”

n) AWS D1.1 “Structural Welding Code – Steel”

o) API Standard 1104 “Welding of Pipelines and Related Facilities”

p) API RP 1111 “Design, Construction, Operation, and Maintenance of Drilling

Hydrocarbon Pipelines”

q) ASME/ANSI B31.3 “Chemical Plants and Petroleum Refinery Piping”

r) API RP 14C “ Recommended Practice for Design and Installation, and Testing

of Basic Surface Safety Systems for Drilling Production Platforms”

s) API RP 14E “Recommended Practice for Design and Installation of Drilling

Production Platform Piping Systems”

t) ASME Boiler and Pressure Vessel Code

u) Instrument Society of America (ISA) Recommended Practices

v) API RP 500 “Recommended Practice for Classification of Location for

Electrical Installations at Petroleum Facilities.

3.7.2 Quality Assurance of Design

SPDC will consider a quality assurance which defines certain basic parameters in the

design of the overall project specifications of the various phases / aspects and

components of the project.

To ensure the full realization of the objectives of the project, SPDC has specified the

following basic parameters in the design, which include:

Simplicity and fit-for- purpose design to reduce cost;

Minimization of redundancy in design and pre-investment for future

expansion;

Compliance with statutory requirements;

Life expectancy;

Production availability;

Environment and safety; and

Operability and maintainability

SPDC Chapter Three


At the implementation stage, SPDC will ensure that the above quality objectives are

met by ensuring that:

Design are executed via the use of verified and validated methods and design

tools;

Input parameters to the design are reviewed and checked for inconsistencies

and errors;

All design documents have a clear audit trial with respect to authorship,

checking and approval signatories/authorities; and

Specific quality practices and resources needed to meet the requirements of

SPDC and all regulatory bodies are explicitly defined.

3.7.3 Well Trajectory Design

The BCA well trajectories were designed using Anadrill's computer software

(powerplan). The evaluation of the collision risks with existing and new well

trajectories, using factor as the criterion, show that the collision risks is

acceptable. A separation factor greater than 1.5 was maintained in the top hole

and deeper intervals. To avoid crooked hole, the dogleg severity was limited to

1-2°/100ft in the top hole and less than 5°/100ft in the deeper hole section.

3.7.4 Wellhead Design

3.7.4.1 Horizontal Wells

Conventional or multi-bowl wellhead system can be used for the BCA FDP. For

horizontal wells, this will consist of the following:

11" x 9-5/8" x 5K CHH to be installed on the 9-5/8" casing (complete with

seal assembly, 11" x 7-1/16 x 5K DCB, running tools, side outlet valve).

A solid block X-mas tree 7-1/16" x 5K (with preparation for control line, wing

valve, choke box and SSV).

This option can be used for all the horizontal wells in this development. However four

of the horizontal wells can be slimmed down to 7" surface casing.

For the slimmed down horizontal wells, the wellhead will consist of the following:

SPDC Chapter Three


11" x 7" x 5K CHH to be installed on the 7" casing (complete with seal

assembly, 11" x 7-1/16 x 5K DCB, running tools, side outlet valve).



This option can be used for Benisede R6H, R7H, R7H1 and S1H

3.7.4.2 CONVENTION DEVIATED WELLS

The conventional or multi-bowl wellhead system would be used for the conventional

deviated wells (S1S7T3C* and S7C) and would consist of the following:

13-5/8" x 13-3/8" x 5K CHH to be installed on the 13-3/8" casing (complete

with seal assembly, 13-3/8" x 11 x 5K DCB, running tools, side outlet valve.

A solid block X-mas tree 11" x 5K (with preparation for 2 control lines, wing

valves, choke boxes and SSVs)

However the S7C conventional well would be slimmed down to:

11" x 7" x 5K CHH to be installed on the 7" casing (complete with seal

assembly, 11" x 7-1/16 x 5K DCB, running tools, side outlet valve).



3.7.5 Casing Design

There are two basic well designs for the planned wells in this development. The

horizontal wells are designed for three hole sections viz.:

12-1/4" surface hole 8-1/2" build up section to landing in the reservoir

6" drain hole.

The convention deviated wells will have two hole sections viz.:

16" surface hole 12-1/4" production hole for dual 3-1/2" production tubing.

12-1/4" surface hole 8-1/2" production hole for single 4-1/2" or 3-1/2"

tubing.

SPDC Chapter Three


The casing schemes for the horizontal and conventional deviated wells will be

respectively:

24" SP (driven) 9-5/8" (47ppf, N80) 7" liner (29ppf, N80) 4-1/2"

slotted liner (13.3ppf, N80) or excluder screens.

24" SP (driven) 13-3/8" (68ppf, K55) 9-5/8" (47ppf, N80) for the 16"

surface hole option.

24" SP (driven) 9-5/8" (47ppf, N80) 7" liner (29ppf, N80) for the 12-

1/4" surface hole option.

3.7.6 Well Completion Design

3.7.6.1 New Well Completion Design/Philosophy

The completion designs are simple, proven and fit-for-purpose aimed at maximizing

offtake rates without compromising ultimate recovery and well integrity. The new

wells will be completed in a manner that will minimise well intervention but allow

through tubing well intervention using wireline or coil tubing whenever required to

maximise life cycle value of the wells. Attempt is made to avoid mechanical

complexity associated with existing completions that make well intervention very

challenging. Of the eleven new wells identified in this development, 2 are

conventional and 9 are horizontal. Additionally, there is one existing well identified

for workover.

Conventional Wells Design

Two new conventional wells: Bens-C* and Bens-C (Fig. 3.3) and 1 workover are

planned in this development. Bens-C* will have cemented 9-5/8” production casing

and completed as a two string dual (TSD) with 3-1/2” tubing strings in the S1.0 and

S7.0 reservoirs. Bens-C will be com pleted as a monobore with 4-1/2” tubing on the

S7.0 reservoir with an upside on the S2.0 reservoir. While the workover will be

recompleted as single with a 3-/12” tubing. All the completion intervals need sand

control and will be sand consolidated (SCON) for sand control except when the

interval to be perforated exceeds 12 ft. This is due to higher productivity of SCON

over gravel pack and accessibility through tubing re-entries for well repairs. The

conceptual completion diagrams are shown ahead.

SPDC Chapter Three


Fig. 3.3: Completion Diagram for Benisede C and C*

Horizontal wells

Five horizontal wells in Benisede will be completed as single string with 4-1/2”

tubing while the remaining one will be completed with 31/2” tubing. One of the

horizontal wells in Benisede, which will be completed on T3, will also be completed

on S8 but placed behind sleeve. The production intervals of the horizontal wells will

be lined and uncemented but will have sand control installed. The Sand control

methods selected are WWS and OHGP/ESS. This is because of the relatively

9-5/8”

(SCON)

(SCON)

PRO PO SE D C O M PLE T IO N FO R BE N ISE D E -C * (T SD )

16 ”

7”

S C O N

PRO PO SE D C O M PLE T IO N FO R BE N ISE D E -C (M O N O BO RE )

24”

13-3/8”

SPDC Chapter Three


unconsolidated nature of the reservoirs, which require sand control installation to

minimise sand production. The two horizontal wells in Akono would be completed as

single string with 4-1/2” tubing. The sand control method will be WWS and SL

respectively. Slotted liner will be used in the more consolidated sand (F3.0). The only

horizontal well to be drilled and completed in Opomoyo on the F2.0 reservoir will be

completed as a single string with 5-1/2” tubing due to the high rate expected (15000

b/d). Slotted liner can be deployed in the horizontal section since the sand is fairly

consolidated.

Plate 1: A well-head in the study area

3.8 Gas lift Requirement

Currently, the reservoirs in BCA are producing naturally and can sustain flow to ca.

70% BSW. 3D-reservoir simulation using MoRes was used to quantify incremental

recovery from gaslift. Incremental recoveries in wells that benefit from gaslift range

SPDC Chapter Three


from 0.18-12.45 mstb. Many new wells in Benisede showed incremental recoveries

due to gaslift. Hence all new wells planned in Benisede will be equipped with gaslift

mandrels. Only a few existing completed strings showed incremental recoveries from

gaslift since most wells are swept by encroaching aquifer due to production from

updip wells (new wells which are crestally positioned inclusive). Eleven existing

strings have gaslift mandrels installed. Hence, existing wells requiring gaslift will

either be workedover to install gaslift mandrels or through tubing orifice check inserts

will be used. Lift gas requirement for BCA is estimated at a maximum of 7 mmscf/d

at optimum injection pressures of 1000-1500 psig.

The Akono and Opomoyo deep reservoirs have high GOR and will not require gaslift.

3.9 Production Commingling

Production commingling opportunities are limited in the of Benisede development

due to single targets in most wells planned. However, crude sampling for geochemical

fingerprinting analysis is in progress. When completed, geochemical feasibility

studies to determine if production allocation using GFA is possible in BCA and the

number of end-members that can be combined. The results of these will be

incorporated in the final plan of the two conventional wells and one horizontal well

(Bens-T3H which is also completed on the S8 interval which is behind in the base

case).

Also, smart wells experiences acquired from the successful deployment of Smart Well

technologies across the group and other companies will be monitored and learnings

adopted for future development opportunities in Benisede.

3.10 Well Safety Enhancement

Some wells in BCA were identified during the field review, which require safety

enhancements. The table (Table 3.0) summarises the current status of these wells and

plans in-place to address any outstanding safety issues.

SPDC Chapter Three


Table 3.0: The Current Status of BCA Wells and Safety Plans

Wells Safety Issues Status Plans for Rectification Time and

action party

Bens –1L/S High Casing Head

Pressure

Presently

safe.

Continue to monitor and

bleed-off. If pressure builds

up, Wire-line work required

to locate and isolate the

point of communication. If

unsuccessful , well will be

plugged and secured

Q1’ 2003

PCW:PTC/W

EL

Bens –4S Com-unit will not

operate on auto

Com-unit

now operate

on auto

It is planned to fix the COM

units to operate on auto or

change them out.

Closed out

Bens –14 Com-unit will not

operate on auto

Com-unit

now operate

on auto

It is planned to fix the COM

units to operate on auto or

change them out.

Closed out

Bens –

17L/S

Inaccessible slots

due to water hycinth.

17L Com-unit will

not operate on auto

Com-unit

now operates

on auto but

access to

slots still

covered by

water

hycinths

Maintain access to slots by

regularly clearing the

weeds. It is planned to fix

the COM units to operate on

auto or change them out

Monthly

PCW/STS2

Bens-9L Leaking SCSSV C.I for

Leaking

SCSSV

A wireline barge to be

deployed to changeout

leaking SCSSV and restore

well back to production in

Q1’2003.

Q1 2003

PCW:PTC/W

EL

Bens –

22L/S

Inaccessible slots

due to water

hycinth.22L Com-

unit will not operate

on auto

Slots still in

accessible

and com-unit

still not

operating on

auto


regularly clearing the

weeds. It is planned to fix

the COM units to operate on

auto or change them out

Q1 2003

PCW/STS2

Bens –6L/S Inaccessible slots

due to water hycinth

Slots now

accessible


regularly clearing the weeds

Closed out

Bens –

16L/S

Inaccessible slots

due to water hycinth

Slots now

accessible


regularly clearing the weeds

Closed out.

3.11 Drilling Rig Selection

The major drivers for rig selection are SPDC's drive to reduce impact on the

environment, increase production, increase operational efficiency and reduce well

SPDC Chapter Three


capex. A cluster-drilling rig is expected to meet most of these requirements and is

therefore the preferred rig type.

The other key factors in the rig selection are the rig rate and operational efficiency

(contractor experience, competence of staff and equipment up time). Although the

fields in BCA are not known for severe hole problems, there are few deviated wells

(six in Benisede field; max 40° in Benisede-8) and no horizontal wells. In view of the

more complex nature of the new wells and the need for well construction efficiency

the rig should be equipped with a top drive.

The minimum specifications/requirements for the swamp drilling rig are as follows:

MODU Swamp Barge

Type Cluster Drilling (minimum 6 wells)

Operating Envelope 16 ft x 8 ft

Moon Pool Area >40 ft x 20 ft

Water Depth 10 - 14 ft

Drilling Depth 15,000ft (measured depths)

Mast 1,200, klbs (9-5/8" 47# csg to 12000ft)

3.12 Mud Systems

Water-based mud and Pseudo-oil based mud will used in different hole sections. The

mud weights for each hole section will be based on drilling experience in the field as

well as STABOR simulations (especially for the build-up sections of horizontal

wells).

3.12.1 Surface Hole (16" for Conventional or 12-1/4" for horizontal)

Water based mud (WBM) will be used drill surface hole sections of horizontal or

conventional wells. Typically Bentonite/CMC spud mud will be used to commence

Draw Works

TDS TDS-4S or TDS-3H ≥ 33000 ft-lbs. (torque rating)

BOPs 13-5/8" x 5000 psi minimum

Mud pumps Up to 1200 gpm; Up to 5000 psi surface pressure

Mud Tanks Capable of handling POBM and WBM. ≥ 3000 bbls storage

Bulking Capacity ≥ 9000 cu. Ft.

Deck load ≥ 2500 short tons

Environmental Aspects Dry location concept

Security Ability to keep out unwanted visitors

SPDC Chapter Three


drilling and converted to KCl/Polymer below the base continental (typically below

4000 ft tvd) where shale layers will be encountered.

3.12.2 Build Section (8-1/2" for horizontal)

The build up section of horizontal wells to landing point will be drilled with pseudo-

oil based mud (POBM) to advantage of the performance benefits of POBM in terms

of borehole stability and lubricity. However, drilling with POBM present some

challenges with respect to the management of drill cuttings in accordance with

regulatory (DPR/FEPA) requirements.

3.12.3 Production hole Section (12-1/4" for Conventional wells)

The production hole section (i.e. below surface casing shoe) of conventional deviated

wells will also be drilled with pseudo-oil based mud (POBM) for similar reasons and

challenges as stated for the 8-1/2" build up section of horizontal wells. The POBM

mud cake clean up is not expected to present production problems since the

production intervals will be perforated after casing and cementing.

3.12.4 Drain Hole (6")

The 6" drain hole sections of horizontal wells will be drilled with water based mud.

The mud will be calcium carbonate weighted KCl/Polymer mud. This is preferred to

POBM or barytes weighted WBM because of concerns about mud cake clean up after

the well is brought into production. Calcium carbonate mud cake can be cleaned up

easily using a specially formulated weak acid recipe. However the ongoing cited

could result in the used of POBM for this hole section.

3.13 Cementation

Class A cement slurry or lightweight (gradient: 0.650 psi/ft) Class G cement slurry

can be used to cement surface casings. The lightweight slurries will have heavy tail

slurry to ensure better casing shoe integrity. To avoid losses the surface casing will

not be cemented to surface. The top of cement for surface casings is expected at

±3000 ftah. The surface casing will be re-cemented from surface to below the

stovepipe using a metal petal basket.

Production casings and liners will be cemented with heavy (gradient: 0.821 psi/ft)

class G cement slurry. The top of cement in production casing for conventional

SPDC Chapter Three


deviated wells would be at least 500 ftah above top shallowest hydrocarbon bearing

interval in line with SPDC and regulatory requirements. The 7" liners shall be run

with liner hangers with integral packers to avoid the need to drill cement on top of

liner after cementation.

All steps will be taken to ensure good primary to avoid costly remedial squeezes,

which may not achieve the required objectives. For hole section with gas bearing sand

intervals gasblok additives will be added to the slurry.

3.14 Waste Management

Waste management during the BCA FDP Phase II project shall be in line with

FMENV regulations while striving to reduce, re-use, or re-cycle. All wastes that

cannot be re-used or re-cycled will be properly disposed. Waste water-based mud

slurry and brine will be re-injected into the CRI well at Opukushi-19. Water based

mud cuttings and psuedo-oil based mud cuttings will be processed with solids control

equipment to reduce mud on cuttings. The cuttings will then be treated at the TDU at

Forcados Terminal after which it will be disposed at designated dump sites (Kokori).

Sanitary wastes will be handled by biological treatment on the rig while domestic

waste will be transported to dedicated SPDC handling facility in Jeddo. Paper waste

shall be recycled at the waste recycling depot in Ogunu.

Spent lube oil and diesel spills will be collected in dedicated storage tanks and taken

to the TDU for treatment. Other industrial wastes such as plastics, metals, rubber and

wood will be segregated on site and collected in designated baskets. The wastebaskets

will be transported to Ogunu for recycling. Detailed waste management methods are

presented in chapter eight of this report.

3.15 Project Schedule

The BCA FDP project shall be placed on the long-term drilling sequence and shall be

executed within the 2004 – 2008 business planning cycle inputs (i.e. submission of

project forecasts and economics for corporate ranking).

SPDC Chapter Three


The drilling was originally scheduled to start in 2005 but is now delayed because of

alignment required with the Southern Swamp Integrated Oil and Gas Project

(SSIOGP) to harness the expected Associated Gas (AG) to the Liquefied Natural Gas

(LNG) train in line with the flares out date of 2008.

Figure 3.4 shows the project schedule for the proposed project.

SPDC Chapter Three


FIGURE 3.4: BENISEDE PHASE 2 PROJECT PLAN

BENISEDE PHASE 2 CAMPAIGN2004 2005 2006 2007 2008 2009 2010

REVIEW IN LING WITH

SSIOGP

DRILLING PHASE

LAY FLOWLINES

AGG START UP

SPDC

EIA of Benisede Catchment Area FDP June, 2005 72 of 253

3.16 Production Operations Plan

3.16.1 Production Facilities

Production facilities in the Benisede Catchment Area comprise wellheads, flowlines

ands a flowstation.

Current well locations and wellhead facilities

Current data on Benisede field completion is presented in Table 3.1.

BCA fields are situated in a swampy terrain. Hence, all the existing wells have

conductor supported swamp wellhead platforms located in dredged slots. All the BCA

reservoirs have produced to date on natural drive although 11 strings are equipped

with gaslift mandrels.

SPDC


Table 3.1: Current Benisede Field Completion Data

Table Benisede Field Completions Data

Well

Type of

Well String GLM?

Data

Completed

Flowline

Length (m)

Size of

Flowline

(inch)

Year

Flowline

Installed

1 Vertical 001L Aug-96 841 4 1995

001S Aug-76 841 4 1995

001V Mar-76 825 4 1992

2 Vertical 002T Jul-76 2068 4 1995

3 Vertical 003T Jul-76

4 Vertical 004L Dec-76 2025 4 1995

004S Dec-76 2025 4 1995

004V Dec-76

5 Vertical 005T Apr-76 1904 4 1996

6 Vertical 006L Oct-76 995 4 1992

006S Oct-76 995 4 1992

9 Deviated 009L YES Jan-81 1611 4 1995

009S YES Jan-81 1611 4 1995

009V Jan-78

10 Vertical 010L YES May-78 1662 4 1995

010S YES May-78 1661 4 1995

11 Vertical 011L Apr-78 1964 4 1995

011S Apr-78 1964 4 1995

13 Vertical 013T Require G/L 690 4 1996

14 Deviated 014L Sep-79 1865 4 1995

014S Sep-79 1865 4 1995

15 Vertical 015L Sep-79 976 4 1995

015S Sep-79 976 4 1995

16 Deviated 016L Oct-79 1565 4 1995

016S Oct-79 1565 4 1995

17 Vertical 017L Require G/L Feb-80 1285 4 1995

017S Feb-80 1284 4 1995

18 Vertical 018L Require G/L Mar-80 1228 4 1995

018S Mar-80 1228 4 1995

19 Vertical 019L YES Oct-82 2560 4 1996

019S YES Oct-82 2560 4 1996

20 Vertical 020T YES Nov-81 997 4 1996

21 Vertical 021L YES Dec-82 1050 4 1996

021S YES Dec-82 1050 4 1996

22 Deviated 022L YES Dec-82 1057 4 1996

022S YES Dec-82 1057 4 1996

AKONO FIELD

1 Vertical 001L(C.I) May-96

001V(L) May-96 6900 6 1996

001S May-96 6900 6 1996

OPOMOYO FIELD

1 Vertical 001L Jun-96 7200 6 1996

001V Jul-96

001S Aug-96 7200 6 1996

The Flowstation

SPDC


The existing Benisede flowstation (Plate 2), commissioned in 1976, is a standard

SPDC swamp piled flowstation with a nominal capacity of 60MBD. The station

consists of two process trains of 30MBD capacity each, all on a single deck. Each

train consisting of a high-pressure (HP) separator, low-pressure (LP) separator and

Surge vessel operates in series. The station is equipped with a Test separator used for

statutory well testing.

Plate 2: Benisede Flowstation

The current flowstation also has eight (8) inlet manifold skids with forty-eight (48)

ligaments. Out of these, 11 are presently not in use. Each of the manifold skids

contains six 3” ligaments and four (4) headers (Test, HP1, HP2 and LP), with pipings

rated at ANSI 600#.

The flowstation is equipped with a single test separator. The Directorate of Petroleum

Resources (DPR) requires that each well be tested at least once a month. Well tests

are also required for well performance monitoring and hydrocarbon accounting.

Crude oil from the wells is directed to either test, HP or LP inlet manifold headers

depending on the flow line pressure. From the inlet manifold individual headers run

to each separator via automatic shut down valves. The LP separators share a common

SPDC


header and isolation valves are provided between the two LP separators. Each of the

HP separators has a separate inlet header. There are inter-connecting pipings between

the trains for operational flexibility.

All the production separators are two phase (gas-liquid) separation vessels operating

in series. The HP crude after degassing in the HP separator, flow to the LP separator

and from there to the surge vessel. The low-pressure wells flow directly to the LP

separator and from there to the surge vessel. The HP, LP and surge vessels pressure

are set at 150, 50 and 6 psig respectively to optimise liquid production and minimise

liquid carry over to the flare.

Crude oil is evacuated from the flowstation by centrifugal pumps installed

downstream of the surge vessels into the delivery line via the metering skid. The

flowstation is equipped with 5 sulzer pumps each with a nominal capacity of 20MBD.

Crude is exported through a new 8” line directly to Trans Ramos pipeline, and the old

12” x 21.2km delivery line via Isampou manifold.

Only a small quantity of produced gas is utilised as instrument gas and fuel gas for

gas engines and generator sets. The rest are routed through the appropriate HP and LP

gas headers to the 16 “ flare gas header en-route the flare.

The shortcomings of the present facility are:

• Requirement of 24-hour resident manning

• Pneumatic instrumentation with attendant venting and relief.

• Intensive maintenance

• Non-dependent Community Assistance

• Facility Constraints, e.g. increasing pump pressure due to high back-pressure

in export line

• Community problems

• Non-segregated drains

• Manual operations

• Logistics problem

• Age of the facility (above 25 years)

SPDC


Utilities

Power/HP Fuel/Instrument Gas Systems

Utility gas required for flowstation instruments, power and fuel, is tapped upstream of

the HP separator at the Back Pressure Control Valve (BPCV) and routed to the

Instrument and Fuel gas scrubber. The gas is subsequently directed via pressure

regulators into instrument gas filters (in parallel), the fuel gas scrubber (for pump

drivers) and power gas scrubber (for electricity generators) before reaching the

various users.

Utility Air

A skid mounted diesel-engine driven air compressor unit (standard Ingersoll Rand T

30 Model 7100) supplies the start air required for kicking off all gas engines in the

plant. The air receiver is off-skid mounted.

Electric Power Supply Systems

A gas-engine driven generator (Cat 3306) provides electric power requirement in the

flowstation. This is rated for continuous duty at 281KVA, 415/240 volts at a nominal

speed of 1500 rpm. The rating is based on meeting the minimum flowstation

requirements. The electric power supply system comprises other utility items such as

lubricating system, instrumentation and control, mode selector switch, protection

devices, starting system and fuel gas system.

The gas engine driven generator is complimented by a diesel-engine driven generator

(CAT D3406), rated for continuous duty at 225 KVA 415/240 volts and a nominal

speed of 1500 rpm. This generator is operated as standby machine when the gas-

engine electric generator is out of service or during extended shutdown. It is designed

to be manually started and take over power generation each time the primary

generator is out of service.

Flare System

Currently, the remainder of utilised process gas is sent to the flare system. This

consists of two 16" diameter flare headers teeing off from a single bulk 16” main

header. The flare comprises two 30” horizontal flare barrels complete with a flare tip

SPDC


and flare pilots. A Flare Liquid Knockout Pot for removing liquids from the flared gas

is installed along the flare line to minimise liquid carryover to the flare. The

maximum instantaneous flaring rate during emergency is the blowdown rate. The

normal continuous rate is 30mmscfd and the minimum rate 0.2 MMscf/d or less

during periods of reduced oil production.

Metering Facility

Crude oil metering system

The existing crude oil metering system consists of four parallel connected 6" positive

G6-S7 displacement meters with mechanical counters, installed on the 8” discharge

line. There is provision for a fifth meter. Each train has an installed capacity of 34,000

bpd and is provided with inlet and outlet block valves to permit their removal for

servicing. Each is also provided with a basket strainer.

Other process control facilities provided to the metering skid include a dial

thermometer, a pressure transmitter connected to the CAO System, a pressure and

temperature recorder and a high-pressure trip device connected to the CAO System.

Test separator

The test separator is equipped with two Postive Velocity (Rotron) meters and a Daniel

Senior Orifice meter on the liquid and gas outlets respectively. The latter meter is

provided with flow and pressure recorders.

Additional meters have been installed on all the production separators' gas outlet lines

to monitor the gas produced / flared.

The test separator is used for periodic testing of individual wells in line with statutory

requirements. Its set pressure depends on the pressure regime of the well being tested.

When a HP well is being tested, the outlet liquid flows to the LP separator for further

degassing and from there to the surge vessel. When a LP well is being tested, the

outlet liquid flows directly to the surge vessel.

The Future Facility

SPDC


It is desirable to have a station adequately sized for future new oil and one that is

better aligned with new corporate operating philosophy. Hence, this station must be

designed for a fail safe, unmanned operation with auto restart. CAO/Restart

monitoring must be installed on facility and logistics centre. A station attendant will

however be required for a 24 hours monitoring of the facility and to provide minimal

intervention on ad hoc basis particularly for Emergency Response duty like spill

control. It will however be required to provide some training to station attendants to

achieve a level of production competence needed for this task.

New Oil and Gas Facility

The following is a description of the green field facility upgrade option selected for

this project:

Process Description

A new Integrated Flowstation (IFS) will be built. It is designed to be as much as

possible similar to the existing flowstation such that similar equipment is utilised to

optimise sparing and ultimately reduce cost of training of operators. The old plant will

be decommissioned and abandoned as soon as the IFS is hooked-up.

The IFS will be barge based and situated adjacent to the existing Benisede

flowstation. The main facilities will include two 45 Mbpd production trains, gas

gathering and booster compression and sand monitoring/removal appliances, besides

the required utility and support systems for unmanned operation. Electric power will

be imported from the Central Power Generation plant at the Tunu CPF via underwater

cables.

Each production train will consist of a LP Separator, HP Separator and a Surge Vessel

(SV). The LP and SV gas will be gathered and boosted to HP pressure to join the HP

gas for export to Tunu CPF for further compression and processing. The operating

conditions of the IFS are tabulated below:

SPDC


Pressure [bar(g)] Temperature [°°°°C]

HP LP SV HP LP SV

9.5 - 15 3-6 0.5-0.3 30-40 30-40 30-40

Crude oil is evacuated by 4 variable speed electric driven pumps in a 4 x 33%

configuration. Each pump has a capacity of 30 Mbpd and rated discharge pressure of

about 90 barg.

Inlet Manifold

The inlet manifold skids will provide some 72 ligaments with pipings rated at ANSI

1500# for the tie-in of the existing and new incoming flowlines to the IFS.

Future Facility Utilities

Power/HP Fuel/Instrument Gas Systems

Gas from the LP separator is used as fuel gas. The fuel gas system configuration

consists of a fuel gas KO (knock out) drum and fuel gas filters (2 x 100%).

The fuel gas system distributes fuel gas to the Flare header (purge) and Flare pilots.

Other users where blanket gas is required include: open drains tank, sand collection

tank and chemical storage tanks

Utility Air

The instrument air system consists of an instrument air receiver and instrument air

packages (an n+1 sparing arrangement is assumed). The package includes

compressors, filters and dryers. Instrument air is supplied to the instrument air

distribution system and, under pressure control, to the utility air system.

Electric Power Supply Systems

Electric power will be supplied to the IFS from Tunu CPF through underground cable.

An emergency diesel engine driven generator will be provided to supply essential

services when main power is unavailable. Emergency power supply will be specified

during the conceptual engineering phase.

Flare System

SPDC


A flare system is included for the following service requirements:

• Emergency blowdown

• Maintenance de-pressurisation

• Pressure relief operations

• Long term operational flaring in the event of compression or gas export system

outage

• Operational drainage ( low pressure liquids from the booster compressor suction

scrubber)

The flare system consists of flare collection headers routed to the flare knock-out

vessel. Liquid from the flare KO vessel is pumped to the process. Vapour is routed to

a vertical flare located off-site.

A flare ignition panel and pilot burners (flame front propagator type with propane

bottle gas supply) are included.

3.16.2 Campaign Operations and Maintenance

Operations and Maintenance will be carried out on campaign basis. Production and

maintenance team for Southern Swamp - 2 District will be based in Tunu Logistics

base on a “week on – week off” basis where remote monitoring of the Benisede

facility among others will be conducted. Visits will be made to the stations for routine

operations activities and preventive maintenance although the flow-station attendants

shall be present in the facility 24hrs/day on 12hrs/day shift. Boat requirement for

well-head operations and other necessary work will be integrated into the district

requirement and co-ordinated centrally at the logistics base.

Ad hoc manning accommodation for operation and maintenance purpose and other

logistics requirement for manning gas gathering/lift facility will be provided on the

MPF.

Campaign Maintenance

A team of maintenance personnel comprising all required skill will carryout

routine and planned maintenance on the equipment in the facility. The team,

SPDC


which will be based in the Field Logistics base in Tunu, will take care of the

facility along with others in the district.

Maintenance Objectives/Strategy

The following are the maintenance objectives for BCA facilities:

• To ensure the safety and security of people, environment and equipment in

accordance with statutory and company requirements throughout the lifetime

of the facilities.

• To maintain technical integrity, with high reliability to guarantee uninterrupted

crude oil production.

• To allow for flexibility and expandability in design of facilities for further

integration of other SPDC facilities into the utility support services of the

station.

• To minimise operating costs of facilities.

To achieve these objectives the maintenance strategies as laid down in the asset

maintenance policies and guidelines will be adopted as appropriate.

Manning

Production operation will be carried out by an integrated team designated for the

entire district and shall meet the demands required to maintain the integrity of the

station and optimise production. The production staff (per rota) shall be of the

following levels:

• 1 Team Leader/Area Production Supervisor

• 1 Instrument/Electrical/Mechanical Supervisor

• 2 Operator/Foreman

• 4 Fitters (Mechanical, Electrical and Instrument) with more emphasis on

Instrument/Electrical depending on Team Leader/Area Supervisor’s discipline.

The station attendants shall be on 12 hr shifts (2 per shift) while others will be on duty

from 0700 hrs - 1900 hrs daily whenever the need arises. They shall however be

available for emergencies subject to management approval.

SPDC


The Tunu logistics centre will have enough accommodation to accommodate all staff

with provision of overnight facility for extra staff per shift. In addition

accommodation will be provided at the flowstation site for one Production foreman

who may be on site on ad hoc basis and 2 station attendants. Security patrols will be

installed at the flowstation area. No night sailing rules (Reference: No Night Sailing

Policy of August 1998) shall be strictly adhered to.

Process Monitoring, Control & CAO

The process control and shut down systems shall be fail safe with minimum operator

intervention. Consideration should be given to upgrading the currently designed

Flowstation as part of development modification, in line with the current company

safety standards and specifications.

Major equipment will be started locally (exception being electric driven equipment

with adequate control) and sufficient information/interlocks shall be provided to a

safe start up. Emergency shutdown system (ESD) checks shall be carried out at six-

monthly interval in line with regulation (Mineral Oil and Safety Regulations of 1997)

to ensure integrity while wellhead checks shall continue at the stipulated intervals.

The current Computer Assisted Operations philosophy requires that data points be

presented as electronic signals as a building block for the CAO system

implementation strategy. Where available, systems shall be based on the open-system

infrastructure.

Equipment Selection

New flowlines shall be designed to withstand maximum closed-in tubing head

pressure (CITHP) attainable in the network, according to the standard flow line design

philosophy. Old lines shall be replaced to the same standard when due, i.e. in

accordance with corporate guideline for 14-years swamp flow-line replacement.

The flow station shall be designed for at least 95% availability. A sparing philosophy

of “N+1” shall be applied to key equipment e.g. pumps, generators, air compressors

etc. where N is the peak number required for normal effective operation. Crude

evacuation pumps shall be electric motor driven centrifugal capable of delivering high

SPDC


volume. Variation from this philosophy shall be subject to management’s approval

based on positive results of overall system effectiveness and equipment vulnerability

studies. Where possible, equipment and instruments shall be common with that used

elsewhere in SPDC.

Well Testing and Metering.

In line with statutory requirements (Mineral Oils and Safety Regulations, 1997) well

testing shall be carried out for each well at least once a month to establish gross

production rate and GOR.

On the gross liquid outlet of the test separators, meters shall be installed that can

measure with a design accuracy of at least +2%. The metering system shall operate

with a turn down from 10,000 to 100 b/d, usually this is achieved through a single 3”

Coriolis meter. A higher capacity meter shall be installed if high gross wells are

brought on stream.

The gas lines of separators shall be designed to ISO 5167 with the intention of

achieving an accuracy of at least + 2%.

Coriolis meter will be used for export metering. The integrity of the meters shall be

determined by frequent maintenance. The meters shall continue to be regularly proved

by differential method. The station water cut shall be determined from BS&W

measurement reading from the Coriolis export meter and compared with computed

results obtained from individual well’s test figures. Gas meter shall be installed on

each of the gas lines and the flare for accurate measurement of gas produced and

flared.

Isolation Draining and Cleaning

All non-routine operational jobs in the station shall be covered by the “Permit-To-

Work” system and Job Hazard Analyses carried out to ensure safety of People,

Equipment and Environment. Isolation shall be such that an item of equipment or a

system can be separated from and not be affected by a live plant. Thus allowing work

to be carried out safely and efficiently on an item without danger from other adjacent

live equipment.

SPDC


Drains shall be designed to allow for segregation of hazardous and non hazardous

liquids as follows:

• Process drains shall be collected through closed drain headers into vessels to be

re-injected into the process, stream by electric-driven pumps.

• Continuously Oil Contaminated drain like bleeders, sample points which

shall be collected through closed drain headers into vessels to be re-injected into

the process stream.

• Accidentally Oil Contaminated drains like wash water, skid drain that shall be

collected into drip pans into the saver pit and the mixture of oil and water is to be

re-injected into the process stream.

• Storm water drain (from roof tops etc) shall be routed directly to the river or tanks

for routine washing purposes.

Thus the process area shall be roofed. Good Housekeeping shall be encouraged at all

times in the facility with adequate provision of adequately labelled waste bins and

waste segregation in line with SSA Waste management principle and ISO14001

standards.

Safeguarding Systems

Fire detection systems are provided in high-risk areas (transfer pumps, generators

etc.) in line with company policy. Fire hydrants and portable fire extinguishers will be

placed at strategic location to fight small incipient fires. In the event of an

uncontrollable fire outbreak, personnel will be evacuated according to laid down

evacuation procedures.

The two levels of shut down systems (ESD and OSD) shall be maintained in the

facility.

All trip devices have individual indications and alarms at the DCS. The ESD system

will be fail safe. With electronic instrumentation, full function tests of ESD systems

shall be carried out at least twice a year.

SPDC


All facility and field monitoring/testing equipment shall be inspected regularly in

accordance with SPDC maintenance procedure guide and mineral oil safety

regulations (Mineral Oil and Safety Regulations of 1997). Individual maintenance by-

pass shall be installed for each instrument to facilitate on-line testing.

Instrumentation

Instrumentation will be designed for remote status monitoring, calibration and

configuration. Reliability of the instruments will allow for on failure maintenance.

Application of AIMS

All maintenance activities will be based on SAP-compliant company approved Asset

Integrity Management System (AIMS). The technical integrity of assets will be

maintained using a computerised maintenance management system (i.e. IMMPOWER

or SAP R/3 when available), again to be applied in compliance with SPDC

maintenance policies. Accessibility will be provided to the system via the divisional

IT server Network at all key locations.

Activity Planning

An Operations Reference Plan shall be developed for the project and shall form the

framework for planning for the facility. An annual review of the 5 years Integrated

Operations Activity plan (IOP document) will be conducted, based on the latest

company business plan for the program period. Firm projects with associated budget

commitment will be logged in a 2-year integrated activity plan. The execution plan

shall be discussed monthly, during the 90 days integrated operations meeting where

the actual date for the execution of the projects are determined based on production

optimization and shutdown requirements. 14 days Activity scheduling shall be used to

capture activities firmed up for execution.

Spare Parts

For new equipment, operational and insurance spares shall be identified by the

production function in line with vendor recommendations and SPDC requirements.

Two years operating spares and special maintenance tools will be provided as part of

the initial equipment purchase and should be available on site prior to hand-over.

Spare Parts Interchange-ability Records (SPIRs) shall be provided by the vendors,

SPDC


which will be reviewed by the Area team before stocking of the spares. The use of

electronics SPIR will be actively pursued.

Equipment Handling & Site Access Requirements

Facilities and special equipment shall be designed for the handling of equipment and

material where required. Good access shall be provided for on-site maintenance

activities without need to interfere with non-related components. Design of the facility

layout shall incorporate ease of access considerations for overhead cranes, jigs and

personnel.

All duplicated and auxiliary systems shall be segregated so that one can be maintained

while the other is in operation.

Workshop Facilities

The divisional workshop shall continue to provide assistance in the following areas:

• Testing and calibration of Mechanical, Electrical and Instrument components

• Major overhaul of rotating equipment

• Machining and fabrication of simple parts

In addition, a workshop shall be provided in the Tunu Field Logistics Base (FLB)

which shall serve the purpose of second line maintenance for BCA besides other

facilities in the district. It shall take care of all electrical, mechanical and instrument

repairs requiring more than routine and planned maintenance.

3.16.3 Materials and Logistics

Central warehousing

All supplies of lubricants, chemical fuel and catering requirements shall be regular in

accordance with current supply strategy. A standard jetty with loading and off-loading

davit crane installed is already available for this purpose. To prevent shortage and

optimize storage, a central warehouse will be provided in Tunu FLB which will serve

as the hub for Benisede and other facilities in the district. Materials will be ordered,

stored and administered centrally for the district from the warehouse.

SPDC


Transportation

Transportation to and from the facility shall be by air or boat. Transport and logistics

shall be administered centrally at the FLB for optimisation purpose. For smooth and

effective operations, the following shall be provided:

Item No/Frequency

Operational boat 4 trips per week

Police patrol boat 1 per day

Chopper flights 4 return flights (minimum) per week

A helipad shall also be provided on the flow station barge and constructed to SPDC

standard specifications. In the event of an emergency, transport shall be requested

through the laid down procedures.

3.17 Production Operations CASHES Aspects

Community Affairs in Production Operations

All matters concerning community affairs around the facility shall first be directed to

the Production Supervisor who will inform the appropriate sections (Community

affairs). In the event of violent community disturbances which impact on production,

station shall be made safe and staff shall return to base until the problem is resolved.

Electricity shall be provided to the neighbouring communities and tied to the facility

to ensure interdependency.

Safety in Production Operations

Where hazards cannot be eliminated, they shall be identified, assessed, registered and

controlled, should loss of control occur, all existing recovery systems and procedures

shall be put in place to reduce the effect of such incident. Hazard registers shall be

reviewed annually and updated as required. Portable fire extinguishers and fire

hydrants shall be strategically located for fire fighting and checked at set intervals by

the fire department. Escape routes shall be clearly marked to the mustering point.

Hazardous areas shall be well defined.

SPDC


All safety measures presently in place will be maintained as follows:

• Job hazards analysis and toolbox meetings before embarking on a job.

• Wearing of PPE for designated areas.

• Prohibition of alcohol in the facility.

• Prohibition of night sailing.

• Prohibition of use of petrol engine and open roof speed boats for operations.

• Regular emergency drills.

• Prohibition of smoking in designated areas.

• Restriction of uncertified swimmers from the facility.

Health Aspects of Production Operations

Local, SPDC and Group’s Seven Minimum Health Standards shall be adhered to at all

time. Caterers shall be checked 6-monthly by MDW to check food handling

hygienic standards. A well-equipped first aid box shall be available in the

facility for first aid purposes only. Severe or more serious cases will be

addressed according to MEDEVAC & MEDRESCUE procedures.

Environment Aspects of Production Operations

In compliance with Group Minimum Environmental Expectations and ISO 14001,

any excess gas shall be flared and not vented into the atmosphere. Hazardous and

non-hazardous drains shall be segregated. The contents of the saver pit shall be re-

injected into the surge vessel while all contingency plans for pollution control shall be

maintained. Where discharges are unavoidable, they shall be closely monitored and

minimised. All generated waste shall be disposed of according to SPDC waste

management procedures and EIA standards. Records of such shall be kept according

to ISO14001 standard.

Measurement of the flare quality for gaseous effluent and sampling for aqueous

effluent shall be conducted in line with legislation requirement.

Security Aspects of Production Operations

There shall be regular patrols of wellheads and flow lines at day times. The security

patrol boat shall be centrally located in Tunu FLB and shall conduct regular patrol and

SPDC


shall respond to distress calls. Future design should incorporate modification to

restrict unauthorised access (security fence/cage).

3.18 Well Decommissioning/Abandonment

All wells that have no economic value will be decommissioned and abandoned in line

with SPDC Well Abandonment Policy. Four wells in Benisede field (Benisede-2, -8, -

9, -12) have reached the end of their productive lives are due for abandonment. One

of them (Benisede-8) is being considered for re-completion as a cutting re-injection

well.

Given the advantage of campaign abandonment, the decommissioning/abandonment

of the wells that have currently reached their productive live will not be carried out

during this round of development. They will be shut-it and suspended till such a time

when sufficient candidates will be available to allow campaign abandonment.

However, the cost for well decommissioning/abandonment is usually captured as part

of SPDC economics.

SPDC


CHAPTER FOUR

4.0 DESCRIPTION OF ENVIRONMENT

4.1 General

This chapter presents the environmental baseline description of the proposed Benisede

Catchment Area (BCA) Field Development Project area. The baseline was produced

using the two-season Benisede Catchment Area FDP Baseline Study Report and a

single season ground-truthing in October 2003.

The details of the methodologies adopted for data acquisition for each of the

environmental components and the Impact indicators are described in Appendix II

while the sampling location map (Map 2) is provided in Appendix 1.

4.2 Description of Existing Environment

4.2.1 Relief/Topography

The BCA field is covered with freshwater swamp with galloping terrain composed of

alternating ridges and gullies. The topography of the area is low lying with some

depression. Raffia palm, oil palm, ferns and grasses dominate the field. The area is

drained by two main water bodies (Bomadi and Brass Creeks).

4.2.2 Climate and Meteorology

The weather condition is determined by the location of the area in relation to the

fluctuating position of the Inter-Tropical Convergence Zone and the Inter-Tropical

Front (ITF). The weather of BCA FDP area is influenced by these tropical

continental and maritime air masses, which are associated with the north-east and the

moisture-laden south-west winds, respectively. The climatic components of the

project area are discussed below.

Temperature and wind

The average maximum and minimum temperatures measured in the field during the

dry season was 29.8oC and 23.02

oC respectively while the maximum and minimum

temperature ranges measured during the wet season were 30.9 – 31.5 o

C and 23.1 –

22.3 o

C. The existing climatic records obtained from the synoptic station indicate that

SPDC


the mean ten years (1989-198) maximum temperature for dry season is 33.23 for

March, 28.5 for July and 32.1 for December. Full monthly maximum temperature for

the last 20 years is shown in Table 4.1.

Two main winds, southwest (SW) and the northeast (NE) winds are generally

influential on the weather in the study area. However, a third wind, the North-South

wind has also been reported in the area. The north–south wind is known to be

strongest during the dry season (November – March). It accounts for about 32% of the

annual winds within the Niger Delta area during this period. (NLNG, 1997).

SPDC


Table 4.1: Mean Maximum Temperature in oC Jan. Feb. March April May June July Aug. Sept. Oct. Nov. Dec. Year

33.5 32.9 32.3 32 30.8 29.2 28.3 27.9 29.3 29.9 30.8 31.4 1979 32.8 33.3 32.6 32.1 30.8 29.9 28.5 27.9 29.4 30.1 30.9 31.4 1980 31.3 33.8 32.9 33.2 30.7 30.5 28.4 27.9 29.3 30.2 31.2 32.8 1981 32.6 33.7 33 32.7 31.3 29.5 28.2 28 29.1 30 31.1 32.5 1982 32.9 35.8 35.9 33.2 31.8 29.7 28.6 27.8 29.3 30 31.1 31.3 1983

32.8 33.9 32.9 32.7 31.4 30.8 29.5 30 29.5 30.1 30.9 31.7 1984 32.5 34.6 33.7 31.8 31.3 30.1 28.9 28.6 29.2 29.9 31.2 31.2 1985 32.8 32.9 32.3 33.1 31.7 30.3 28.1 28.5 29.1 29.7 30.9 31.6 1986 33.5 33.7 32.3 33.5 32.2 31.3 30.1 29.3 29.9 30.3 32.3 32.7 1987 33.1 34.7 33.1 33.1 32.1 30.8 29 28.9 29.1 30 32.1 30.9 1988

Mean: 32.78 33.93 33.1 32.74 31.41 30.21 28.76 28.48 29.32 30.02 31.25 31.75

33.1 35.1 32.6 32.5 31.1 30.5 28.7 28.7 29.5 30.3 32.1 32.5 1989 31.9 34.1 35.9 33.5 31.7 30.7 27.9 28.5 29.1 30.3 31.5 31.3 1990 32.5 32.9 32.7 31.9 31.9 30.7 29.2 28.7 29.6 30 31.3 31.5 1991 32.3 34.6 32.7 32.8 32.1 29.7 28.1 27.7 29.5 30.2 31.4 32.7 1992 32.9 34.1 32.4 32.1 31.9 30 28.5 28.5 29.9 30.9 31.7 1993 32.8 34 33 32.7 31.5 29.9 28.1 29.1 30.2 32 33.2 1994

32.5 34.2 33.2 33 31.4 30.6 28.9 29.3 30 30.2 32 32.1 1995 33.1 33.4 32.2 32.3 31.9 30.4 29.3 28.3 28.7 30.3 32.8 32.9 1996 31.9 34.1 35.5 33.5 31.9 30.7 27.9 28.5 29.1 30.3 32.5 33.5 1997 32.6 36.9 32.1 33.1 31.4 29.3 28.9 29.1 28.5 31.1 32.1 30.2 1998

Mean: 32.56 34.34 33.23 32.74 31.68 30.25 28.55 28.58889 29.3 30.38 31.96667 32.16 Source: Federal Department of Meteorological Services, Oshodi, Lagos( now, Nigerian Metrological Agency)

SPDC


Table 4.2: Monthly Total Rainfall Records in mm Jan. Feb. March April May June July Aug. Sept. Oct. Nov. Dec. Year 0.3 166.9 221.5 255.2 191 407.3 295.9 316.3 215.1 280.5 120.7 11.4 1979

7.6 27.8 64 158.7 360.8 265.4 375.3 281.7 359.3 431.7 212.1 0.5 1980 75.5 27.5 140.2 102.1 311.4 272.6 318.2 305.7 337.4 171.4 66.8 0 1981 30.2 37.9 107.6 147 238.3 204.2 431.4 230 360.2 143.2 58.3 3.2 1982

0 TR 33.1 114.2 141.3 183.5 310.9 154.4 324.4 304.7 19.8 45.7 1983 0 61.6 71.4 170 251.4 321.2 225.2 232.8 502.7 143.6 111.4 6.3 1984

9.5 8.9 154.8 208 296.8 402.5 391.2 344.3 359 161.3 51.6 1.8 1985

12.5 60.1 97.3 121.4 156.7 168.7 513.9 282.1 401.1 361.5 107.8 0 1986 0.5 119.5 166.7 90.5 121.4 337.8 308 381.1 410.5 213.1 95.4 16.8 1987 5.4 4.5 119.9 165.8 274.9 467.4 329.6 307.1 463.9 226.6 34.7 21.1 1988 0 56.9 77.9 249.1 311.5 248.2 180.7 430.7 341.7 171.9 TR 55.6 1989 21 15.4 14.7 122.7 144 127.5 446.7 578.1 323.4 148.5 59.1 72.2 1990 TR 80.9 105 107.5 432.1 256.5 360.2 310.1 139.1 171.6 111.1 20.3 1991

58.7 3.6 178 89.9 178.8 170.2 388.5 271.1 260.3 271.5 87.9 13.7 1992

0 43 158 247.5 138.5 326.8 438.5 426 368.7 266.8 xx 20.9 1993 37.4 66.8 80.9 128.9 372.6 256.3 462.3 xx 342 218.8 93.9 0 1994 79.6 15.6 118.3 120.1 362.5 246.6 398.7 333.6 319.6 413.1 29.6 53.6 1995 TR 130.4 113.9 320.9 363.8 160.5 241.3 229.4 478 272.8 22.8 TR 1996

23.3 18.6 96.4 174.5 330.1 353.1 360 305.6 207.4 133.2 247.2 29.9 1997 22.6 36.9 87.6 188 279.1 414.6 369.8 247.3 489.3 265.4 136.7 32 1998

40.9 51.2 106.6 186.4 291.6 232.9 294.1 257.4 453.5 510.6 73.5 TR 1999 11.6 7.2 59.2 190.2 202.3 181.5 420.3 245.4 454.9 153.1 126.3 16.9 2000 31.2 2.4 156.2 118.2 314.7 745.2 336.9 309.9 365.3 137.2 108.1 28.1 2001

0 79 75.8 103.3 118 324 285.4 556.7 265.4 283.5 67 28.1 2002 173 86.2 93 169 174.2 254.7 840.9 206.4 535.3 239.6 98.6 4.1 2003

SPDC


Source: Federal Department of Meteorological Services, Oshodi, Lagos( now, Nigerian Metrological Agency)

SPDC Chapter Six


Table 4.3: Mean Monthly Temperature and Rainfall Records

Location Time

(hr)

Relative

Humidity (%)

Max. Temp.

(oC)

Min. Temp

(oC)

Rain Fall

(mm)

Ojobo 10.30 78 27.0 23.5 311.5

Amabolou 11.45 88 29.8 22.0 295.2

Peretorugbene 1.00 81 28.5 23.5 321.6

Torugbene 8.30 79 31.5 22.6 424.6

Flowstation 8.30 78.5 32.0 23.5 401.2

Source: Benisede Catchment Area FDP Baseline Study Report (Dec., 2002)

Rainfall

Within the BCA FDP area, rain falls throughout the year but over 80% of it occur in

the months of May to September. The 25-year rainfall records (1979 - 2003) indicate

a mean rainfall of 373mm, 19.3 and 107.9mm for the months of July, December and

March respectively. The single highest rainfall record is 840.9mm recorded in July

2003. (Federal Department of Meteorological Services, Oshodi, Lagos).

Relative Humidity

The average relative humidity recorded in BCA FDP area was 80.9% with sunny and

cloudy weather in the dry season. However, the long term mean monthly relative

humidity for the region at different times of the day show that higher relative

humidity (RH) values are recorded at 0900 h for both wet and dry seasons. This warm

humid climate and high relative humidity measured in the BCA FDP area is due to the

seasonal variation of the Inter-Tropical Front and the geographical location of the

Niger Delta.

Wind Speed and Direction

The predominant wind direction within the BCA FDP area is southwest (80%) and

rarely northeasterly (20%) with low wind speed throughout the area. The wind speed

within the BCA FDP area during the field study ranged from 6.5 – 8.5 knots, with an

average of 7.5 knots (Table 4.4).

SPDC Chapter Six


Table 4.4: Wind Speed and Direction within BCA FDP Area (Dry Season)

Location Wind Speed Wind Direction Weather

Condition

Time Hours Speed (knots) Time Direction

Ojobo 9.45-11.45am 2 7.2knots 9.45a.m SW; NE SCW

Peretorugbene 1.30-3.30pm 2 6.5knots 2.00p.

m

SSW SCW

Torugbene 9.45-12.45am 3 7.5knots 10a.m SSW SSMB

Flowstation Area 12.45-3.45pm 3 8.5knots 2.00p.

m

SW SBW

Amabolou 8.45-10.45am 2 6.5knots 10a.m SW CW

Key to Weather Condition

SCW = Sunny and cloudy weather, SSMB = Slightly sunny with moderate breeze

SBW = Sunny and breezy weather, CW = Cloudy weather

4.2.3 Air Quality and Noise

The results of in-situ air quality studies in the BCA FDP area are presented in Table

4.1a in Appendix III (dry season) and Table 4.1b Appendix III (wet season). The

assessed solar and heat radiation values ranged from 0.0 to 1.85 kW/m2 (dry season)

and from <0.01 to 1.76 kW/m2 (wet season). The most intense solar radiation (1.85

kW/m2 in the wet season and 2.22 kW/m

2 in the dry season) were measured at the

flowstation whereas the highest heat radiation value of 2.22 kW/m2 was obtained

from the flare site. The smoke density measured at the flare site was measured at 1.20

Ringlemann number. Other noxious gases measured are shown in Tables 4.1

(Appendix III). Volatile Organic Carbon (VOC) was not detected (below detectable

limit, BDL) at all the sampling stations while SOx and NOx were within

FMENV/DPR limits (Table 4.1 Appendix III).

The noise levels measured within BCA FDP area ranged from 52.5 dB (A) at Ojobo

primary school to 93.5 dB (A) at the flare site in the dry season. There was no

significant variation in the noise levels measured in the wet season (Table 4.2

Appendix III). The recorded noise data are within tolerable limits of 80 –100 dB (A)

specified by FMENV and DPR.

SPDC Chapter Six


4.2.4 Soil, Agriculture and Land Use Studies

Soil The most prevalent features of the soils within the BCA FDP area are those that are

related to poor drainage and seasonal flooding. They are mineral soils formed on

almost flat lowland areas. They belong to the freshwater alluvial deposits (Anderson,

1967).

The texture of the soil in Benisede field is mainly sandy loamy. The amounts of

colloidal particles (silt and clay) are small, leading to excessive leaching of nutrients

in the soil. The mean soil pH value is 4.40 and strongly acidic.

Electrical conductivity of the soil in Benisede field is low (mean: 66.89 µS/cm) but

suitable for most crops if recommended amounts of fertilizer are used. The total

nitrogen contents could be due to the tide coverage of these soils, which prevent

minerealization of organic matter into component nutrients. The concentrations of

available phosphorus are low and below the 15.0ppm recommendation critical level.

Agriculture

Agriculture in the area is dictated by, climatic factors, soil properties and landscape

features of the coastline. The locals in the BCA FDP area are mainly subsistence

farmers and often practice mixed cropping. Crop combinations include cassava, yams,

vegetables, maize and okra. Plantain, banana and cocoyam are also cultivated in the

area. However, plantain and banana are observed to be scattered around the bushes

while cocoyam is commonly planted on dredged materials along the banks of the

creeks. Although the crops are cultivated in small scale in the area, they were

observed to be flourishing, indicating the suitability of the soil for such crops.

Fish farming is also a common agricultural practice in the area. Common fishing

methods include: backwater netting, canoe drift netting and, hook and line.

Both raphia palm and oil palm (Elaeis guineensis) are prominent in the BCA FDP

area. The oil palms are harvested from wild groves.

SPDC Chapter Six


Physical Characteristics of soils within BCA FDP area

The physico-chemical characteristics of the soils within the BCA FDP area are

reported in Table 4.3 in Appendix III.

Soil Texture

The soils of the BCA FDP area are generally coarse textured and sandy loam. The

textural distribution varies from sand to sandy clay loam in both surface and

subsurface soils. The mean clay contents is above 10 percent and 9 percent for surface

and subsurface soils respectively while the silt content averaged 21 percent in both

depths. The silt/clay ratios indicate that the soils are made up of young parent

materials with low degree of weathering (Van Wambeke, 1962; Asomoa, 1973; Edem

and Ndon, 2001). These results show that the soils are likely to have weatherable

minerals needed for plant nutrition.

Plate 3: Soil sampling using a hand-held auger

S

o

il

Sample

0- 15 cm Depth 15 – 30 cm Depth

SPDC Chapter Six


Table 4.5: Particle Size Distribution in Soils of BCA FDP area

S = Sand, SL = Sandy Loam, SCL = Sandy Clay Loam

Chemical characteristics of soils within BCA FDP area

The chemical properties of soils within the BCA FDP area are presented in Tables 4.3

(Appendix III).

Soil pH

The soils are strongly acidic with mean pH values of 5.4 and 5.2 for surface and

subsurface soils respectively. The high acidity may have resulted from the dominance

of acidic cations, which is the characteristic of soils with kaolinites (1:1) and oxide

clays. The strong acidity will influence the availability of basic cations and hence the

productivity of the soil.

Cation Exchange Capacity (CEC)

The CEC is low with mean values of 6.43 and 6.33 meq/100g for surface and

subsurface soils respectively. The values are however higher in the surface soil than

the subsoil. This may be due to the presence of organic materials or litters on the

surface soil. The low CEC indicates low soil fertility.

Sand

%

Silt

%

Clay

%

Textural

class

Sand

%

Silt

%

Clay

%

Textural

class

SS1 71.6 11.2 17.2 S 67.8 21.7 10.5 S

SS2 66.7 24.9 8.4 S 65.6 25.2 9.2 S

SS5 67.4 23.9 8.7 SL 66.7 24.7 8.6 SCL

SS6 64.4 26.3 9.3 SL 65.2 26.1 8.7 SL

SS8 72.5 17.4 10.1 SL 65.8 20.7 13.5 SL

SS9 70.7 20.6 8.7 S 88.1 8.5 3.4 S

SS12 66.6 22.2 11.2 SL 68.5 23.2 8.3 SL

SS18 72.5 21.9 5.6 S 70.5 21.2 8.3 SCL

SS19 65.3 21.8 12.9 SCL 68.2 18.6 13.2 SCL

SS20 65.5 20.3 14.2 SCL 65.4 24.4 10.2 SCL

Range 64.4-

72.5

11.2-

24.9

5.6-

17.2

65.2-

88.1

8.5-

26.1

8.3-

13.5

Mean 68.32 21.05 10.63 SL 69.41 21.43 9.39 SL

Silt/Clay

Ratio

1.98 2.28

SPDC Chapter Six


Organic Carbon, Total N, C:N Ratio and Available Phosphorus

The organic carbon contents are low in both depths (0-15cm and 15-30cm). The

values are higher in the surface soil than the subsoil Tables 4.3 (Appendix III). The

mean values are 0.99 and 0.48 percent for surface and subsurface respectively. The

higher value for the surface soil may be due to the presence of organic materials,

litters and this is also the zone of maximum root activity (Donahue et al, 1983,

Wahden et al, 1984; Edem and Ndon, 2001).

Similarly, the total N is low with mean values of 0.24-0.39percent for surface and

subsurface soils. The C:N ratios were recorded as 2.4 (surface) and 3.3 for sub-

surface. The soils have low available phosphorus (P) with mean values of 3.74 and

2.89 mg/kg for surface and subsurface soils respectively. Like the organic carbon

content, the values are higher in the surface soil than the subsoils. This is because

available P is known to be associated with organic matter (Ibia, 1994; Edem and

Ndon, 2001).

Electrical Conductivity

The values ranged from 20.8 to 96.4µs with a mean value of 66.89µs for the surface

soil and from 20.4 to 91.5 µs with a mean value of 61.21 µs for the subsoil. The mean

values were higher in the surface than the subsoils.

Chloride

The chloride content varied from 144 to 1027 mg/kg with a mean value of 463.35

mg/kg for the surface soils and from 123 to 1021 mg/kg with a mean value of 441.7

mg/kg for the subsurface soils (Tables 4.3 in Appendix III). The mean value is

higher in the surface soil than the subsoil. The presence of chloride in soils is known

to influence the uptake of some nutrients, for example phosphorus.

Total Hydrocarbon (THC) Contents

The THC contents ranged from 0.68 to 7.10 mg/kg with mean value of 3.52 mg/kg for

the surface soils and from 0.71 to 6.24 mg/kg with a mean value of 3.41 mg/kg for the

subsurface soils (Table 4.3 Appendix III). The low values may indicate that the

hydrocarbons in the soil are biogenic and not petrogenic in origin (Chemical Society

of Britain, 1975.

SPDC Chapter Six


Heavy Metals

The heavy metal content of soils within the BCA FDP area is reported in Table 4.3

(Appendix III). Iron is the most abundant with a range of 38.12 – 894 mg/kg and

mean value of 403.61 mg/kg for the surface soils while the range for the subsoil is

40.12 – 905 mg/kg with a mean value of 427.95 mg/kg. Generally, the values are

within the range for mineral soil environment (Bohn et al, 1979). However, their

impacts as to the degree of contamination can be highly significant due to the local

edaphic condition. Detection of petroleum associated heavy metals such as nickel (Ni)

and vanadium (V) confirms that the soil environment must have been impacted by

crude petroleum. This may result from operational or accidental spill of crude

petroleum from well-heads or burst flowlines. Such spills may be spread by flood on a

large area of the low-lying soils.

Soil microbiological analysis

The heterotrophic bacterial count of soil samples of the BCA FDP area varied from

1.3x104

- 2.7 x 1010

cfu/g with a percentage hydrocabon biodegraders range of nil to

2.1% in the dry season (Table 4.7 Appendix III). The predominant bacterial

communities in the soil samples of the BCA FDP area were composed of

Pseudomonas auriginosa, Proteus mirabilis; Micrococcus sp; Bacillus subtilis;

Eschericha coli; Klebsiella sp. (Table 4.7 Appendix III). The hydrocarbon degraders

were mainly species of Bacillus, Klebsiella, and Pseudomonas. In the wet season,

heterotrophic bacterial count of soil samples of the BCA FDP area varied from

1.6x106

- 3.6 x 1010

cfu/g with a percentage hydrocabon degraders range of 0.00 to

1.27%.

The fungal counts of soil samples of the BCA FDP area were low and ranged from

1.0 x 104 to 3.5 x 10

7 cfu/mg (Table 4.8 Appendix III). The counts of hydrocarbon

degraders are low with their associated low percentages (0.03 – 1.50%). The

predominant fungal isolates were mainly species of Mucor, Candida, Saccharomyces,

Cladosporiump, Penicillium and Aspergillus. In the wet season, similar trend was

observed (Table 4.8 Appendix III).

SPDC Chapter Six


4.2.5 Vegetation / Land use

4.2.5.1 Vegetation Profile

The vegetation of BCA FDP area is generally homogenous and composed mostly of

two layers of vegetation strata, namely the tree and shrub/herb layers. The tree layer is

composed mostly of pure stands of Raphia hookeri with only scattered freshwater

swamp forest tree species.

Plate 4: Brass Creek – A major drainage feature in the study area (also

showing a palm bush)

Common plant species within the study area include: Raphia palms, Symphonia

globulifera and Pterocarpus santalinoides, Bambusa vulgaris (bamboo), Elaeis

guineensis (oil palm), Anthocleista vogelli (Cabbage tree), Mitryagyna stipulosa

(Abura) Alchornea cordifolia (Christmas bush), which is characteristic of Swamp

forests of Southern Nigeria.. The tree layer was dominated by Raphia hookeri while

the herb layer was dominated by ferns (Cyclosorus sp. and Diplazium sammatii) and

the arrow-head weed, Cryptospermum senegalense.

SPDC Chapter Six


The vegetation of the BCA FDP area is generally a freshwater fringe forest type with

canopy heights of between 5 - 8 metres. The vegetation also consists of emergent tree

species reaching up to 15 metres in some cases. The vegetation cover is between 60-

80%, with patches of bushes resulting from farming activities (newly cleared farm

plots, cultivated farmlands and abandoned or fallow farm plots). A major

distinguishing characteristic of the forest in this area is the dense tangle of lianas and

other climbers. (NEST, 1991).

4.2.5.2 Land use types and Floristic Composition

There are four distinguishable landuse types within the BCA FDP area. They are:

(i) Built-Up

(ii) Farmlands/Home gardens,

(iii) The freshwater swamp forest, and

(iv) Water Bodies.

Built Up

These consist mainly of towns, villages, fishing settlements and Oil and Gas facilities

within the study area. The major towns and villages in the area include: Ojobo,

Peretorugbene, Tamogbene, Amabolu and Norgbene. and Akarino. There are also

small fishing settlements spread along the banks of the creeks. Oil and Gas facilities

in the area include a flowstation, wellheads, pipelines, a helipad and two houseboats.

The built up area make only about 6% of the total land use of the area.

Farmlands/Home gardens

The floristic composition of the farmland/Home gardens species, which incidentally

reflect the herbaceous components of the vegetation are presented in Table 4.6. The

major herbaceous and grass species are Pennisetum purpureum, Pennisetum

polystachion, Hyperrhenia sp, Ageratum conizoides, Aspilia africana, Chromolaena

odorata and ferns, Pteris sp and Dryopteris sp.

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Plate 5: A farmland in the study area

The farmlands/home gardens, which constituted about 15% of the vegetation found

especially at the edges of the creeks/slots, had crops such as cassava, plantain, sugar

cane, cocoyam, potato and medicinal plants (e.g. Bryophyllum).

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Table 4.6: Agricultural Landuse types with commonest plant species

Landuse

Type

Commonest Plant Species Life-Form/

Plant status

%

Abundance

Farmlands

/Home

gardens.

Zea mays, Vernonia amygdalum,Musa paradisiaca, M.

sapientum, Manihot esculenta, Xanthomonas sp.,

Colocasia sp., Saccharum officinarum, Ipomoea

batata, Carica papaya, Capsicum anuum, Dioscorea

alata, Hibiscus esculenta.

Crop plants

10% Bryophyllum pinnatum, Cassia alata. Medicinal

plants

Panicum laxum, Echinochloa pyramidalis, Axonopus

compressus, Saciolepis sp., Phyllanthus amarus,

Chromolaena odoratum, Acroceras sp., Ageratum

conyzoides, Pennisetum purperum, Commelina

benghalensis, Heliotropium indicum.

Weeds on

crop farms

Fresh-

water

swamp

forest

Raphia hookeri, Anthocleista vogelli, Mitragyna

stipulosa, Elaeis guineensis, Musanga cercropioides,

Alstonia boonei, Ciba pentandra, mytragyna ciliata,

calamatus decratus, Uapaca stuadtii, berlinia,

Pandanus, togoensisNapoleonaea vogelli.

Mesophanero-

phytes

75%

Raphia hookeri, Alchornea cordifolia, Funtumia

elastica, Baphia sp., Spondias mombin, Cassia alata,

Ficus sp., Macraranga spinosa, Lophira alata, fiscus

congensis, Ceiba pentandra, Cesestis afzelii,

Asplenium africanum, Ancistrophyllum sp.

Microphanero

-phytes

Cassia alata, Baphia sp., Elaeis guineensis, Raphia

hookeri, Chromolaena odorata, Capsicum sp.

Nanophanero-

phytes

Piper sp., Pennisetum purpureum, Bryophyllum sp.,

Dioscorea sp., Smilax kraussiana.

Chamaephyte

s

Costus afer, Aframomum sp. Cryptophytes

Commelina benghalensis, Axonopus compressus,

Panicum laxum, Acroceras sp., Saciolepis sp.,

Echinochloa pyramidalis.

Hemicrypto-

phytes

Phyllanthus amarus, Heliotropium indicum,

Chromolaena odorata, Ageratum conyzoides, Pteris

sp., Cyclosorus sp.

Therophytes

Diaplazum sammattii Epiphytes

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Aquatic

Macro-

phytes

Eichhornea crassipes, Azolla africana, Pistia

stratiotes, Slavinia molesta, Lemna sp.

Free floating

15% Nymphea lotus. Floating leaf

type

Cyrtospermum senegalense, Echinocloa pyramidalis,

Saciolepis sp., Alternanthera sessielis, Aeschyonomene

indica, Vossia cuspidata.

Bank type

The freshwater swamp forest

The freshwater swamp forest account for about 60% of the total land use of the study

area. The forest vegetation can be classified into three plant species groups, that is

Hemicryptophytes, therophytes and epiphytes. It is predominated by Palm trees

(Eleias guneensis), Rafia palm (Raphia hookerii), Umbrella plant (Musanga

cerclopoides and Alstonia bonnei). Alchornea cordifolia forms the main bush/shrub

species, occassionally accommodating clusters of Banana, Plantain, the rubber plants

(Havea sp) and Coconut (Cocos nucifera). Some cultivated species of Guava, Mango

(Mangifera indica) and bush mango (Irvingia gabonensis) were also present

especially near the settlements/villages or towns.

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Plate 6: Farming on dredge-spoil along bank of Bomadi Creek

In elevated areas due to dredge spoil dumped along the slots, grasses such as

Pennisetum purpureum, Saciolepis, Cyclosorus, ferns and members of the Araceae

family (eg. Cryptospermum senegaleuse) dominated the herb stratum. These dredge

spoil dumps are used for cultivation of plantain, musa paradisiaca and cocoyam,

Xanthosoma sagittifolium.

Aquatic Macrophytes

The slots to the wellheads within the BCA FDP area are covered by aquatic

macrophytes creating difficulty to boat traffic from local fishermen. The aquatic

macrophytes of the BCA FDP area include Echinochloa sp, Azolla africana, Pistia

stratiotes and Nymphea lotus. Species such as Cryptospermum senegalense, Vossia

arspida and Saclolepsis sp were also observed. The aquatic macrophyte population of

the BCA FDP area was dominated by Eichhornea crassipes (water hyacinth), Vossia

cuspidata, (grass) Echinocloa sp (grass) Pistia stratiotes (water lettuce) and Salvinia

molesta (aquatic fern). Others were Azolla africana, Lemna sp, Saclolepis sp,

Alternanthera sessielis, Aeschyonomene indica and Cyrtospermum senegalense. They

were concentrated in the slots more than in the creeks and creeklets. There was high

species diversity and density of these aquatic macrophytes encountered within the

BCA area and thus has the potential to develop into excessive populations that can

cover the entire water surface of the wellheads slots.

The relative abundance of the different groups of plant species within the study area

(BCA FDP area) indicates that Firm Soil plant species constitute about 75% of the

vegetation; the aquatic macrophytes constitute 15%, while the farmland/Home

gardens form 10% of the vegetation.

4.2.5.3 Plant Species Diversity of the BCA FDP Area

The plant species diversity of the BCA FDP area are summarized in Table 4.7. The

mean plant density in the herbaceous layer was 62 No./m2 in the fresh water swamp,

345 No./m2 of aquatic macrophytes and Farmland species had 20 No/m

2. The tree and

shrub cover showed a density of 565 No./ha and 4620 No./ha in the swamp forest and

farmlands, respectively. Epiphytes were observed on the palm trees.

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The species diversity index was 0.455 for the Freshwater swamp and the aquatic

species and 0.475 for the Farmland species.

Table 4.7: Plant Species diversity and agricultural landuse

Vegetative/Agricultural

landuse type

MEAN PLANT DENSITY Species Diversity

Index

Herbaceous

layer (No./m2)

Tree and shrub or

crop layer (No./ha)

Freshwater swamp

Aquatic Macrophytes

Farmlands

62

345

20

565

-

4620

0.455

0.455

0.475

Pathological Studies

The vegetation in BCA FDP area presents a generally healthy bill though with a few

cases of disease prevalence e.g, Sigatoka on plantain (Musa paradisiaca) and rust on

raffia and oil palm. The Chlorophyll content is expressedly high, occassioned by the

absences of leaf yellowing and/or chlorosis. Leaf damage resulting from the

defoliation by insects was however noticed. Disease symptoms and the severity

indices, as well as causative agents are presented in Table 4.8

The oil and raffia palms had the rust disease with very light disease severity indices

(Table 4.8). Few populations of the arrowhead weed (C. senegalense) had the mildew

disease. The Musanga plants as well as the Hibiscus esculenta had moderate to severe

infection as shown in the defoliation of the plants caused by the larva of insects

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(caterpilar). The plantain and banana plants also had moderate to severe infections of

sigatoka disease and this affected the sizes of bunches from the plants.

The pathogens were however limited in their occurrence and did not pose any threat

to the healthy appearance of the general vegetation.

Table 4.8: List of Plant Species/disease analysis within BCA FDP Area

Plant species Disease

symptoms

Disease

severity

Index

Identified causative

agents

1. Freshwater swamp

forest

Elaeis guineensis Rust 1 Curvularia sp.

Alchornea cordifolia Leaf spots 2 Cercospora sp.

Musanga cercropioides Defoliation 3 Larvae (Cartepillar) of

Insect

Raphia hookeri Rust 2 Curvularia sp

2. Aquatic macrophytes

Vossia cuspidata Leaf spots 2 Puccinea graminis

Cyrtospermum

senegalense

Sooty Mildew 2 Erysiphe sp.

3. Farmlands

Manihot esculenta Cassava mosaic

disease

1 Virus

Musa paradisiaca Sigatoka 3 Mycosphaerella musicola

Ipomoea batata Leaf spots 2 Cercospora sp

Musa sapientum Sigatoka 2 Mycosphaerella musicola

Saccharum officinarum Rust 1 Curvularia sp.

Hibiscus esculenta Defoliation 2 Larvae (Cartepillar) of

insect

Plant Tissue Analysis

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The results of plant tissue analysis from BCA FDP area are presented in Table 4.4

(Appendix III). The values were within normal/standard acceptable limits. However,

ferric ion concentration was quite high (76.65ppm) in Cryptospernum senegalense.

This is not unexpected because of the tendency of this plant to accumulated ferric ion

in its tissues. The value was still within non-dangerous limits.

The result of plant tissues assessment of matured leaves usually reported for the area

indicates that the range of concentrations of N, P and K, are 2.00 – 2.24mg/l, 0.18 –

0.29mg/l and 1.23 – 1.30, respectively. Other parameters are presented in Table 4.4

(Appendix III).

4.2.6 Wild Life / Biodiversity Studies:

The wildlife observed and sighted in BCA FDP area during the field study include

Insects, Molluscs, Amphibians, Reptiles, Birds (Aves) and Mammals. The wildlife

types encountered are presented in Table 4.9.

The inventory of invertebrate fauna was diverse and consisted of forest dwelling

species dominated by ants, beetles and millipedes. Many genera and species of

arthropods were recorded. Ants, flies, butterflies and grasshoppers were a common

feature within BCA FDP area. Some species of bugs, dragon flies and damselflies

were also recorded. The mollusca fauna was represented by the presence of the giant

African land snail, Archachatina marginata suturalis and the garden snail,

Limicolaria aurora. Freshwater periwinkle, Tympanotonus fuscatus were also

predominant in the BCA FDP area.

Most of the mammals are crepuscular, feeding in the early hours of the day or just

before dusk. Rodents and pottos dominated the mammalian class. Forest dwelling

species in the swamp area and, seed and insect-eating species in the developed area

dominated avifauna of the BCA FDP area. The bird species recorded by sighting, nest

observations and call sounds include the white egrets, kites, weaverbirds, owls and

hawks.

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Different species of reptiles and amphibians were also noticed. Prominent among

these were Agama agama (Common lizards), monitor lizards, Gecko, frogs and

Snakes.

Table 4.9: List of Wildlife species within the BCA FDP Area

Taxa Common names Scientific names

Phylum Arthropod

Dictyoptera Cockroachers Blatella sp

Gryllidae Crickets Gryllus sp

Gastropoda Water snail Lymnea sp

Water snail Physa sp

Giant African land snail Archachatina marginata

suturalis

Garden snail Limicolaria aurora

Periwinkle Tympanotonus fuscatus

Amphibians

Frog Dicroglossus sp

Frog Ptychadaena sp

Toad Buforugularis

Toad Xenopolis sp

Reptiles

Lizard Agama agama

Skink -

Gecko -

Snake -

Birds (Aves)

Cattle egret Egretta garzetta

Senegal fire-finch Lagonstica senegala

Forest robin Cercotrichas leucostcta

Turtle dove Streptopelia semitorquata

White-faced owl Accipiter badius

African swift Collectoptera affinis.

Palm swift Cypsiurus parvus

Carrier Hawk Polyboroides radiatus

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Village weaver Ploceus cucullantus

Red eyed dove Streptopelia semitorquata

Common bulbul Pydnonotus barbatus

West African River Eagle Haliaetus vocifera

Hornbill Lophoceros semifasciatus

Yellow wagtail Budytes flavus

Mammalia

(Mammals)

Giant rat Rattus sp

Potto Perodictius potto

Mona monkey Cercopithecus mona

White-bellied pangolin Manis tricuspts

4.2.7 AQUATIC STUDIES

Surface Water Quality

The major surface water bodies in the project area are Bomadi and Brass Creeks.

The results of the physico-chemical parameters of surface water samples from the

BCA FDP area are presented in Table 4.5 Appendix III.

In-situ measurements of the temperatures of the surface water within the BCA FDP

area ranged from 21.8 to 33.4 0C with a mean of 29.7

0C. Turbidity values varied

between 2.1NTU and 56.0 NTU. Total dissolved Solids varied from 30.5 to

110.8mg/l and electrical conductivity values were between 26.7 and 99.2mg/l. The pH

values indicated a weak acidic range of values (pH 5.7-6.8) while Bicarbonate values

ranged from 0.56 to 3.31mg/l. The Chloride concentrations varied from 26.8 to

99.2mg/l.

Chemical Oxygen Demand (COD) values ranged from 3.7mg/l to 15.3mg/l. Dissolved

Oxygen values ranged from 4.42 to 5.09mg/l while Biochemical Oxygen Demand

(BOD) values ranged from 0.85 to 1.21mg/l.

The concentrations of Na+, K

+, Ca

++, and Mg

++ ions are as follows: 2.51mg/l to

5.74mg/l; 1.87mg/l to 8.74mg/l; 4.87mg/l to 27.29mg/l and 1.83mg/l to 4.34mg/l

respectively. The heavy metal concentrations were generally low. The concentrations

of the Total Hydrocarbon Content (THC) were also low (<0.50mg/l).

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Phytoplankton Studies

The phytoplankton community of the surface water within the BCA FDP area

comprised of 32 taxa belonging to the Divisions Bacillariophyta (16 species);

Chlorophyta (6 species); Cyanophyta (3 species) and Euglenophyta (7 species). The

diatoms (Bacillariophyta) were the most prevalent followed by the Euglenoids while

Microcystis (Cyanophyta) was the most dominant blue-green species being present in

all the stations in the BCA FDP area.

Zooplankton Studies

The zooplankton community of the surface water within the BCA FDP area was

mainly arthropods and rotifers. The arthropods were made up of cladocera,

Conchostraca, Ostracoda and Copepoda. Bosmina longirostris and Bosminopsis

dietersi were prevalent among the cladocerans. The Ostracoda was represented by

Parastenocypris sp, Stenocypris sp and Cypridopsis. The Cyclopoids were dominant

among the copepods. The Rotifera were represented by five families and eleven

species dominated by members of the family Brachionidae. (Brachionus fulcatus,

Brachionus tripos, Keratella tropica, Ceptialodella, Tricocerca, Kelicotia, Lepadella

ovalis, Lecane lutia, Anuraeopsis fissa)

Microbiological Studies

The heterotrophic bacterial count of water samples of the BCA FDP area varied from

1.1 x 106 to 12.5 x 10

6 cfu/ml with low percentage of petroleum degraders (0.01 to

0.90%) in the dry season. The counts were within the range usually obtained from

unperturbed environment (102-10

6 cfu/ml) (Table 4.9 Appendix III). The

predominant bacteria species in the water bodies of the study area were Bacillus sp,

Staphylococcus sp, Pseudomonas sp and Escherichia sp (Table 4.9 Appendix III).

However, in the wet season the heterotrophic bacterial count of water samples of the

BCA FDP area varied from 1.3 x 106 to 12.1 x 10

6 cfu/ml with low percentage of

petroleum degraders (0.1 to 0.9%).

Apart from WS 14 where no fungal growth was observed, the fungal counts of water

samples from the BCA FDP area ranged from 3.1 x 105 to 9.8 x10

5 cfu/ml in the dry

season (Table 4.10 Appendix III). During the wet season, the fungal counts of water

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samples from the BCA FDP area ranged from 3.1 x 105 to 8.2 x10

5 cfu/ml. The

predominant fungal isolates in water samples within the BCA FDP area were Mucor

sp, Cladosporus sp Penicillium sp and Candida sp. The low ratio of microbial counts

to petroleum degraders of below 1.0% indicates that there has been no previous crude

oil input into the water of the BCA FDP area in recent times.

Fisheries Studies

The main occupation of the people inhabiting the field is fishing. Fishing is

extensively carried out by the host communities for domestic consumption as well as

for commercial purposes. Fishing gears include fish traps, conical baskets, hooks and

lines, cast nets, sweep nets and drag net of various mesh sizes. Shellfishes include

shrimps of the families Penaeus notialis (Pink shrimp) and Parapaenopsis

longirostris (Royal shrimp) and the commercially important bivalve mollusc (Egeria

paradoxa) which were mostly picked up by divers operating from dug-out canoes

along the Bomadi and Brass creeks. Fish observed in their natural environment or

bought from the fishermen operating along the creek belonged to the orders

Characiformes, Cypriniformes, Osteoglossiformes, Siluriformes and Perciformes. A

list of the fish species of the water within the BCA FDP area is presented in Table

4.10.

Analysis of the condition factors of the fish species of the water within the BCA FDP

area showed that the fishes were healthy and well fed in a relatively unperturbed

environment. The condition factors were on the average well above 1.0 (the critical

value). The species diversity as well as the density was high. All the fishes examined

did not show any physical evidence of parasitic infestation. There were also no

observation of disease infestation and abnormalities.

Table 4.10: A list of the commonest fish species within BCA FDP Area

FISH CLASSIFICATION FAMILY Abundance

Order Characiformes

Hepsetidae, Hepsetus odoe,

Citharinidae, Citharinus citharius.

4

Order Cypriniformes

Cyprinidae, Barbus batersii 3

Order Osteoglossiformes Osteoglossidae, Heterotis niloticus,

Gymnarchidae, Gymnarchus niloticus.

2

Order Perciformes

Cichlidae, Sarotherodon galiaeus, Tilapia marie,

T.zilli.

4

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Order Siluriformes

Bagridae, Chrysichthys, nigrodigitatus, Clariidae,

Clarias buthupogon

Mochokidae, Synodontis clarias

Schilbeidae, Physailia pellucida

3

Order Mugiliformes Mugilidae,Mugil curema, Liza falcipinnis 3

Order Protopteriformes Protopteridae, Polypterus aneectens 2

Order Momyriformes Momyridae, Gnathonemus petersii, momyrus

deliciousus, momyrus rume, marcusenius psittatus

3

Order Carangiformes Caranx hippos, caranx senegalensis 2

Order Schilbeiformes Schilbe mystus, Eutopius niloticus 1

Plate 7: Tilapia zilli caught at the Benisede Flowstation area

4.2.8 Sediment Studies

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Physico-chemical characteristics

The results of physico-chemical characteristics of the bottom sediments of the BCA

FDP area are presented in Table 4.6 (Appendix III). The pH of the sediment is acidic

with values ranging from 5.2 to 6.3. Texture of the sediment varied from loamy sand

to sandy loam, with low nitrate values ranging from 0.01 to 2.71ppm, the percentage

total nitrogen values ranged from 0.14-0.32. These values are low, and this indicates

active mineralization of organic matter due to decomposition activities. Available

phosphorus concentration varied from 0.4 to 6.1mg/kg. Exchangeable cations Ca, Na,

Mg and K have values ranging respectively from (2.97-11.11mg/l), (0.02-0.72mg/l),

(0.19-10.32) and (0.41-6.23mg/l).

The results of the heavy metal of the bottom sediments of the BCA FDP area are

presented in Table 4.6 (Appendix III). The values are generally high indicating a

concentration/accumulation of these ions /metals in the sediment.

Macrobenthic invertebrates

The predominant macrobenthic invertebrates’ communities of the BCA FDP area are

mostly the fauna inhabiting the bankroot biotope. The Benthic organisms were

represented by the bivalve, Egeria paradoxa. The macrobenthic invertebrates

consisted of 11 taxa belonging to the Phyla Annelida (2 taxa), Arthropoda (7 taxa),

Mollusca (1) and Chordata (1).

The annelids were represented by Dero sp while the arthropods were represented by

Caridina africana (decapod); Hydrophilus picus and Dysticus sp. (Coleoptera).

Cryptochironimus (Diptera), Somatochlora metallica (dragon fly nymph), Beatis sp

(Ephemeroptera), and Edyonurus sp. The density and diversity of the Macrobenthic

invertebrate were generally low throughout the BCA FDP area.

4.2.9 Microbiological Studies

The heterotrophic bacterial count of the sediment samples within the BCA FDP area

ranged from 11.8x108 to 25.4 x 10

8 cfu/g with low counts of petroleum degrading

bacterial isolates and hence low heterotrophic bacterial count to crude oil degraders of

less than 1.0% (Table 4.11 Appendix III) in the dry season. In the wet season, the

heterotrophic bacterial count of the sediment samples within the BCA FDP area

ranged from 11.8x107 to 26.2 x 10

7 cfu/g (Table 4.11 Appendix III). The

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predominant bacterial isolates from sediment samples within the BCA FDP area for

both seasons were Bacillus sp, Pseudomonas sp, and Staphylococcus sp.

The fungal count ranged from 2.56 - 3.65x 106g. The percentage hydrocarbon

degrading fungi varied from 0.25 – 0.92% in the dry season, while the fungal count

ranged from 2.55 x 106 to 5.24 x 10

6 (Table 4.12 Appendix III) with petroleum

degrading fungal ratio of less than 1.0% (Table 4.12 Appendix III) in the wet season.

The low ratio of microbial counts to petroleum degraders of below 1.0% indicates that

there has been no previous crude oil input into the sediment of the BCA FDP area in

recent times.

4.2.10 Geology/Hydrogeological Studies

Geology of the Area

The BCA FDP area lies within the Niger-Delta, its geology is therefore typical of the

Niger Delta Basin. The area forms part of a geological sequence of the Quaternary and

Tertiary formations of the Niger-Delta, consisting mainly of three main geologic

formations, which are:

The Benin Formation;

The Agbada Formation; and

The Akata Formation.

The Benin Formation: This is the topmost layer (Oligocene-Recent), which extends its

limit from West to East side across the entire Niger Delta area and Southwards beyond

the present coastline. The formation is composed of 90% sandstone with shale

intercalations. Its thickness is variable but generally exceeds 1800 meters.

The Agbada Formation: This underlies the Benin Formation and consists of sandstone

and shales. It consists of an upper predominantly sandy unit with minor shale

intercalations and lower shale unit, which is thicker than the upper one. The age range on

the Geologic Time Sequence is Oligocene to Recent.

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The Akata Formation: (Eocene to Recent). It is over 1200m thick, consisting of

discontinuous/undulating clay unit of marine shales probably occurring as lenses.

Overlying these three sequences within the Niger Delta are various Quaternary deposits

or geomorphologic units. Within the BCA FDP area, there are deposits and meander

belts, which are abandoned, meander loops and extensive point bars. It is capped by

natural levees with the crevasse deposits typifying flood plains.

VES Data and Interpretation

Below are the descriptions for each shot point for the five VES stations established

within the BCA FDP area.

VES 1

The response VES curve for this station is a KHA type. Computer iterative interpretation

reveals a four-layered geoelectric model with first layer having a resistivity of 545Ω

corresponding to a sandy clay layer. The second layer has a resistivity value of 342Ω

corresponding to a sandy layer. Other resistivity values obtained correspond to sandy

formation.

VES 2

The response VES curve for this station is a KQA type. Computer iterative interpretation

reveals a three-layered geoelectric model with first layer having a resistivity 823.5Ω

corresponding to a top sandy -silty -clay soil underlain by a clay unit. The unit overlies a

dry weathered sandy unit, while the rest of the geoelectric substrata are likely to be

sandy units.

VES 3

The ABEM response VES curve for this station is a KH type. Computer iterative

interpretation indicates four geoelectric layers. The first layer is the sandy topsoil

underlain by clayey layer that is made up of geoelectric layers 2, while geoelectric layer

3 consist of stratified sand units with resistivity values ranging from 185 to 580Ω.

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VES 4

The ABEM super VES curve indicates an AHK type. The curve shows an undulating

manner of increasing apparent resistivities. The computer iterative interpretation

modeled a three-layered substratum. The first layer could be interpreted as sandy topsoil.

The topsoil is underlain by the second layer, which corresponds to a clayey layer with

resistivity value of 582Ω.

VES 5

The ABEM super VES curve indicates a KHA type. The curve shows a bowl-bell

segment indicating lower resistivities. The computer iterative interpretation indicates that

the first two layers are possibly sandy topsoil underlain by clayey substratum.

Hydrogeology/Ground Water Quality

The stratigraphy of the ten-drilled boreholes revealed a fine to medium grained

unconsolidated sands intercalated with clay lenses and iron sheen. The lithology as

observed within the BCA FDP area are known to have resulted from the combined

forces of depositional actions of the nearby Atlantic Ocean and the currents of the

Bomadi/Brass rivers and their tributaries draining the area.

SPDC Chapter Six


Plate 8: Drilling new groundwater monitoring borehole at Opomoyo.

The aquifers were not confined and the ground to water depth varied from 4 to 6m and

the direction of groundwater flow is from East to west towards the Brass creek.

The groundwater quality assessment indicated a pH range of 6.3 to 6.7. Electrical

conductivity values were generally high (347.5µS/cm to 1261.5µS/cm) indicating that the

groundwaters were fresh to slightly brackish. The borehole water had moderate turbidity

values of 13.8 – 28.5.6NTU.

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Plate 9: Flushing existing groundwater monitoring boreholes at the Benisede

flow-station.

Sodium, Potassium, Calcium and Magnesium concentrations are 27.60mg/l, 18.30mg/l,

32.30mg/l and 21.40mg/l, respectively. The results of the heavy metals analysis indicate

values for Fe, Zn, Cu, Cr, Mn and Cd as 1.45mg/l, 0.45mg/l, 0.05mg/l, 0.32mg/l and

0.01mg/l, respectively. THC values ranged from 0.06mg/l to 0.42mg/l.

4.2.11 Social and Health Impact Studies

Introduction

Major communities within the BCA FDP area are Ojobo in Burutu Local Government

Area of Delta State and Peretorugbene, Tamogbene Oweigbene, Norgbene and

Amabolou in Ekeremor Local Government Area in Bayelsa State.

Social Impact Studies

Demography

The estimated population of the communities within the BCA FDP area is 37,468 (1991

population census) people. The average annual growth rate of Nigeria’s population was

put at 2.83% by the 1991 population census and based on this growth rate, the 1996

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population was projected to be 44,029. Some of the communities within the BCA FDP

area studied include Ojobo (7,204 people), Peretorugbene (9,037 people), Tamogbene

(375 people), Amabolu (4,778 people), Norgbene (2,401 people) and Ekeremor (10,393

people).

The 1991 population census figures of the area are presented in Table 4.11.

Table 4.11: BCA community population

Community Males Females Both 1996 Projection

Ojobo 3,535 3,669 7,204 8,212

Peretorugbene 4,750 4,287 9,037 10,695

Oweifagbene & others 213 207 420 497

Tamogbene camp & others 191 184 375 444

Amabolou 2,472 2,306 4,778 5,655

Ekeremor 5,449 4,944 10,393 12,300

Norgbene 1,305 1,096 2,401 2,842

Obirigbene III 440 391 831 983

Foutoragbene II 550 457 1,007 1,192

Agalawegbene & others 360 312 672 795

Oweigbene & others 178 172 350 414

Source: 1991 Population census of Nigeria

The demographic profile (Table 4.12) shows that 58.6% of the population studied are

males while 41.4% are females. About 39.8% of the population sampled are less than 15

years with age group 5-9 years being the most populated (14.9%). This demographic

profile shows that the communities are dominated by youths and there is high level of

dependency in these communities.

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Table 4.12: Demographic profile of the BCA FDP Area

Age (years) Male (%) Female (%) Total (%) Cumulative (%)

0 – 4 7.5 6.6 14.1 14.1

5 – 9 8.5 6.4 14.9 29.0

10 – 14 5.7 5.1 10.8 39.8

15 – 19 6.9 4.8 11.7 51.5

20 – 24 5.1 3.8 8.9 60.4

25 - 29 3.7 2.7 6.4 66.8

30 – 34 3.9 2.4 6.3 73.1

35 - 39 4.6 3.0 7.6 80.7

40 – 44 2.7 2.1 4.8 85.5

45 – 49 2.8 1.5 4.3 89.8

50 – 54 2.5 1.3 3.8 93.6

55 - 59 2.1 1.0 3.1 96.7

60 & above 2.6 0.7 3.3 100

Total (%) 58.6 41.4 100

The family size distribution of the communities within the BCA FDP area (Table 4.13)

showed that 33% of the respondents have a family size of 5 - 8 people, 21% of the

respondents have 1 – 4 people and 46% of the respondents have above 8 people. These

values show that the communities have a larger family size.

Table 4.13: Family Size Distribution of Communities within the BCA FDP area

Family Size (Range) % Respondents

1 – 4 21

5 – 8 33

9 - 12 27

Above 12 19

Total 100

Ethnography

Peretorugbene and Ojobo are the major communities that own Benisede fields. They are

homogeneously Ijaw, a major ethnic group in the Niger Delta region.

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Plate 10: Consultation with communities (Ojobo)

The Ijaws whose settlements are restricted to the coastal belt, claim to have descended

from a common ancestor that migrated from Benin –Aboh in the hinterland. The cause of

this migration connected with political intrigues for which the Benin Kingdom was

famous.

From “Benin – Aboh”, the Ijaw ancestor is said to have originally settled at Otuokpodu

in Bayelsa state from where all other settlements were founded to the east and west. The

reasons for this movement away from Otuokpodu include both political intrigues, rivalry

for fishing areas and shortage of land, amongst others. This is a recurrent problem

among the Ijaws to date.

Streams of emigrants are said to have left Otuokpodu to found 32 other settlements, 18

in Bayelsa State and 14 in Delta State. Constant emigration and founding of new

settlements now constitute Ijaw social life.

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AMABOLU, THE HEADQUARTERS OF OPOKUDO CREEK LGA IN BAYELSA STATE

MIGRATED FROM OTUOKPODU ON ACCOUNT OF RIVALRY FOR FISHING AREA.

AMABOLU (MEANING A TOWN LOCATED IN THE CREEK) IS ACCLAIMED TO BE

THE ANCESTRAL ROOT OF ALL COMMUNITIES IN OPOROMOR KINGDOM, THE

SEAT OF THE PEREKERE (KING) AND THE HEADQUARTERS OF THE FAMOUS

EGBESU DEITY.

PERETORUGBENE, A SETTLEMENT IN THE BRASS CREEK IS SAID TO HAVE

BEEN FOUNDED BY FUOKEREGHA, A DESCENDANT OF THE AMABOLU

MONARCHY WHO HAD MANY SONS INCLUDING ODOH, SANAH, EKANBARA,

ESIEMOGHARI, DAUNEMIGHA AND TWO WOMEN, TOLU AND EKIERE.

EKERE, THE FOUNDER OF OJOBO, IS SAID TO HAVE MIGRATED WESTWARD

FROM AMABOLU WITH HIS CHILDREN AND NEPHEW NAMED GBESA TO SETTLE

IN ORU –EKEREMO FOU, NOW KNOW AS EGBEMA ANGALABIRI MARKET (FOU).

LATER, GBESA MOVED FURTHER WESTWARD WITH HIS CHILDREN AND

SETTLED AT KRISE CREEK. WHEN ONE OF HIS CHILDREN WAS SAID TO HAVE

DIED AT BOLOU-OJOBO, HE LATER MOVED TO FOUND ADAGBASA AND

ASAKUSA ON THE BOMADI CREEK. A FURTHER MIGRATING STREAM MOVED

FROM BOLOU –OJOBO TO FOUND ADAGBA, NOW OJOBO TOWN IN THE FOLOU

–TORU MAIN CREEK. THE NAME OJOBO WAS DERIVED FROM THE BEAUTIFUL

BRASS COLOUR OF THE WATER (OJOBOYE- OGU).

Culture

Culturally, the Ijaws are a patrilineal people with strong emphasis on monarchy. There is

a very strong filial relationship with extensive extended family ties. Age is accorded due

respect. Old men are referred to as Amaokusuowel and old women as Amaokusuere. The

leadership Cadre is made up of heads of the different household. Community leaders are

selected on the criteria of wealth, leadership qualities and age. Although women play a

subsidiary role in the social life of the communities within the BCA FDP area, they are

very active economically.

Political Organization

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Two levels of political organization, the formal governmental and the local /traditional

administration are operating in these communities. At the governmental level,

Peretorugbene is in Ekeremor LGA in Bayelsa state while Ojobo belongs to Burutu LGA

in Delta state.

At the local/traditional administration level, three tiers of authority are involved. They

include:

(i) The traditional ruler and his chiefs,

(ii) Community development committee, and

(iii) The youth council.

The Traditional ruler and his Chiefs are at the apex of political authority in these

communities but effective political power actually lies in the hands of the members of

executive of the community development committee (CDC) (popularly known as the

community executive). A chairman who is invariably very charismatic heads this

committee.

Committee members are entrusted with the day –to-day affairs of the community. All

visitors are obliged to first of all confer with the chairman and other members of the

executive before activity of any sort is carried out. Without the permission of the

community executive, it is not possible for a contractor or a consultant to carry on any

business related to oil exploitation in the area. The community executive reports to the

traditional ruler and his chiefs.

The third tier of Government/authority in the community is the youth council headed by

a vocal president. The council obeys and accepts the decisions of the higher tiers of

authority. They consult with the community executive and the traditional rulers in all

matters in the community and are not permitted to act on any issue without due

permission. Unlike the formal governmental level where the three tiers of authority are

very effective, the youth restiveness that is common in these communities makes the

traditional administration ineffective.

Economics and Livelihood

Attempt was made to compute earnings from different sources available to

residents within the BCA FDP area. About 27% of residents within the BCA FDP

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area earn over N2000 weekly from fishing while 42% earn less than N500. Over

30% of residents within the BCA FDP area earn less than N5000 from other

sources while 33% earn between N1500 – N2000 from other sources. Incomes

claimed appear quite substantial by national standards or those of Bayelsa and

Delta States where the settlements are situated. What is more, the communities are

rural, a region usually notorious for its poverty especially in the developing

countries. Significantly, the poor physical environment tends to lend support to the

suspicion that the incomes may have been exaggerated.

But the apparent wealth of the communities is counter balanced by the high costs of

living. Costs of living are very high and are not reflected in the living standard.

Consumer’s goods including food items are at least twice as costly as in the

mainland. Fuel costs are particularly high, a somewhat ironical development given

the fact that the area is rich in petroleum. Because of the high fuel costs,

transportation is very expensive. The high costs of living therefore results directly

from the high costs of fuel as traders pass on their transportation expenses to

consumers.

A recurrent socio-economic problem that has since assumed a political dimension is

the issue of unemployment. The exact extent is yet to be quantified but the problem

is directly implicated in the societal turmoil in the Niger Delta region as

unemployed people struggle to make out a living one way or the other.

Quality of life

Quality of life measures the amount and distribution of socio-economic variables such as

electricity, pipe borne water supply system, access road, educational institutions, health

facilities, housing type and a market for the exchange of farm and other products

Electricity

PERETORUGBERE AND OJOBO HAVE FUNCTIONAL ELECTRICITY SUPPLY AND

THE POWER GENERATING SETS ARE SWITCHED ON ONLY AT NIGHT.

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Potable Water

Portable water is not available in Peretorugbene and Ojobo. Even where mono-

pump water project has been completed, they are not functional. People from these

communities depend on water from rivers and creeks.

Road and Transportation

The construction of beachfront road in Ojobo was proceeding during the dry

season field survey and was completed before the wet season field survey. The

terrain in these communities makes road building/construction very expensive and

difficult to undertake.

Plate 11: Dugout canoes – common means of transportation of goods and persons in

the study area.

The menace of floods is one of the greatest problems facing the settlements. Rise in

water levels may lead to the total submergence of houses within the settlements.

Hence adequate action has to be taken to solve the problem.

Transportation between communities is tedious and expensive with the use of

speedboats. The popular passport-19 ply the major communities to mainland towns

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like Warri where traders buy their goods. For short journeys, dugout canoes

(popularly known as hand-paddled canoe) are used and are usually very slow and

precarious as faster boats and river turbulence can make it very risky.

Housing

Most houses within the BCA FDP area are built of reeds and thatch. Along the

shoreline, the houses are built on stilts; though fairly durable, they are not

physically attractive.

Plate 12: A Typical Shoreline Settlement in the Study Area - Peretorugbene

Few modern houses are also found in these communities and are concentrated in

larger settlement and L.G.A. headquarters

The primary and secondary schools that have all benefited from SPDC educational

infrastructure development scheme are additional lifts to the physical decadence of

these settlements.

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Education

Education is one area in which the settlements have witnessed some development.

There are a total of 18 primary and 8 secondary schools distributed almost evenly

in the BCA FDP host communities as shown in Table 4.14. There is however, the

problem of shortage of teachers as all the schools (both primary and secondary) are

understaffed. At present staffing level, the teacher-pupil ratios are 1: 177 and 1:52

for primary and secondary schools, respectively.

School enrolment is skewed in favor of males at both primary and secondary levels.

Boys make up 57.2 percent total enrolment in primary schools while girls constitute

42.2 percent of total enrolment at the secondary level.

The level of physical development in the schools has been enhanced by the visibility

of the schools. Even so, only a few staff quarters and sports facilities exist. The most

notable of the latter is the sports complex at Agidiama consisting of facilities for

soccer and lawn tennis. The facility was built by SPDC.

The national teachers’ institute, Kaduna runs courses leading to the award of

teacher’s certificate in Peretorugbene, Tamogbene and Ojobo. This is part of the

distant education scheme operated by the institute.

Table 4.14: School Enrolment Statistics 2001

Settlement

Primary

Secondary

Schools Enrolment

Teachers

Schools Enrolment

Teacher

Ojobo 4 1521 10 1 1316 13

Peretorugbene 1 1400 4 1 1100 -

2 1815 9 - - -

TTamogbene 1 1612 14 1 1190 7

1 1615 12 1 1310 15

1 923 6 - - -

Agbidiama 1 1606 7 1 1650 10

Total 11 10492 62 5 6566 45

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Sanitation and Waste Disposal

There is no organized system of sanitation or waste disposal within the BCA FDP

area. Domestic wastes are thrown about without order but generally behind or

beside houses or even directly into the river. As houses are usually built without

toilets, human waste is discharged directly into river from which water for drinking

and domestic use is obtained. Domestic wastewater is merely thrown into the street

or just by the house or even directly into river from which water for drinking and

domestic use is obtained. All the settlements, without exception, are in very urgent

need of modern sanitation and waste disposal systems.

Jetties and shoreline protection

Because all the settlements are riverine and liable to erosion, jetties and shore

protection are very important infrastructure facilities. Unfortunately, not much

attention has been paid to this aspect within the BCA FDP area, thus embarking or

disembarking from canoes, boats or other vessels are often hazardous.

Only Ojobo and Peretorugbene have concrete jetties. However, every community

has one or more wooden jetties, which are all in various stages of disrepair.

Health Studies

The health status of an area is a function of the living standard of the people and the

overall quality of the environment. The health status of the people of the project area can

be summarized thus;

(a) Nutitrition

The diet of the local population is mainly locally caught fish (including shellfish).

The average diet is therefore rich in protein, but usually lack vitamins and

minerals owing to the high cost of their source food items. Cassava flour (garri),

one of the staples in the area, is locally produced while rice, which is brought in

from Sapele, Warri, Burutu and other inland communities, is expensive and in

short supply.

(b) Water Supply and Sanitation

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Water for domestic purposes is drawn from hand-dug wells dug within the

neighborhood, streams, rivers and surrounding creeks. Even the completed

mono-pump water projects in the area are nonfunctional. Furthermore,

domestic wastes (including sewage) are freely dumped along the banks of the

creeks and rivers. These wastes become obvious at low tide, littering the

coastline. At high tide, these contaminated water find their way into wells and

other sources of drinking water, thereby transmitting pathogens into the

water. This could be a major reason for the poor quality of life and health

status of residents in the communities within the proposed project area,

which is evident in the high cases of ailments like, cholera, typhoid and

helminthic infections.

(c) Housing

Houses within the area are small, poorly ventilated and overcrowded with an

average of about 5 to 7 persons per room. The overcrowding also aids the quick

spread of communicable diseases.

(d) Smoking and Use of Alcohol

Smoking of cigarette was observed as characteristic habit of the people, mostly

the youths. Alcohol consumption cut across age barriers, both adults and youths

alike, indulged in the use of alcohol.

(e) Health Facilities

Health facilities were generally lacking in the area, even were health centers

existed, they lacked equipment and drugs. However, there were some patent

medicine stores in the communities. Most residents in the area depend on the patent

medicine stores dealers “doctors” for medical attention while critical cases are

taken to Yenagoa or Burutu.

(f) Morbidity Patterns

History and physical examination of the sampled population in the communities

surveyed revealed certain morbidity characteristics. They include:

Fever/frequent headache

Blurred vision

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Diarrhea and vomiting

Skin rashes

Marked weight loss

Cough and Catarrh

Sexually transmitted diseases (not HIV)

(g) Mortality Patterns

From interviews with the sampled population and records from health centers,

mortality rates were high in the children and women (mostly during child

delivery) than in men. This could be attributed to the inability of the traditional

birth attendants to handle complications during labour, poor sanitation and effects

of disease vectors like mosquitoes, etc.

Health Risk Assessment

Various hazards associated with the project are summarized in table 4.16. The

purpose of this matrix is to summarize in a birds’s eye view the different existing

hazards to health within the community, determine the levels to which the community

members are exposed to these hazards and their sensitivities to them. Levels of

exposure have been arrived at through questionnaire administration, participant

observation and review of the relevant literature. Unless certain epidemiologic

conditions relating to agent, host and environment are met, a health hazard may not

necessarily lead to a disease, illness or health condition. Vulnerability scale (1-10) in

Table 4.15, therefore, represents our assessment of the levels of interplay of these

factors within the respective communities to result in susceptibility to the particular

disease condition.

Table 4.15: Health Risk Exposure Matrix (Health Sensitivities)

Health hazard Risk to Health Current

Levels of

Exposure

within

Communities

Sensitivity/Vulnerability

Index (Scale 1-10)

BIO-PHYSICAL

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ENVIRONMENT

Poor air quality met etc Respiratory diseases Moderate 7

High noise levels Hearing impairment

tolerance shift

insomnia.

Moderate 7

Biotic factors

Wild/venomous animals

Disease Vector

Fatalities, injury

(from snake bites,

wild animals)

Disease transmission.

Moderate

High

7

9

Abiotic Factors (Climate

conditions)

Weather related

maladies, vector

epidemiology

High 8

LIFE STYLE

Alcohol and Drugs &

Substance Abuse

Organ damage to

liver, lungs etc,

impaired mental

health tendency to

crime and violence

Moderate 4

Exposure to casual /

commercial sex

STIs Moderate 7

Unprotected sex STIs. HIV/AIDS Moderate 8

Cultural practices Female Gental

mutilation

Low 3

Recreation/stress

management

Hypertension,

coronary problems

Very low 6

Waste disposal and

management

Communicable

diseases

High 9

SOCIAL ISSUES

Inequality Violence Moderate 4

Insufficiency of

Infrastructure

Poor health

preventive and

management

interventions,

insecurity, poor

communication

High 7

Poverty/Personal

income levels

Variety of diseases

and maladies

creating vicious

cycle of disease and

poverty

High 7

Level of crime Injury fatality Low 4

Level of Violence Injury fatality Moderate 7

Level of Education Lake of awareness

on appropriate

preventive and health

management

Low to

Modrate

4

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practices OCCUPATIONAL

HAZARDS

Fishing Activity

(Paddling neting)

Unguinal hernias Moderate 6

Water Transport

(paddling)

Unguinal hernias Moderate 5

Fish

Smoking/Processing

Respiratory

disorders, eye

problems

(conjunctivitis)

High in

vulnerable

population

(fish

processing

womenfolk)

7

OTHERS

POTABLE WATER

INSUFFICIENCY

Water-borne diseases

(cholera, typhoid

etc.)

Very High 6

MALNUTRITION/FOOD

SECURITY

Nutritional maladies

in vulnerable

population

(women/children)

Moderate 4

HOUSING AND LIVING

ENVIRONMENT

Upper respiratory

tract infections.

Diseases

transmission, risk of

fire

Very high due

to

overcrowding

and practice

of fish

smoking

within

habitation

6

DEMOGRAPHIC

PROFILE

More youthful

population liable to

high crime. Violence

and STI levels

Moderate 6

TRAUMA (INJURIES

FROM ACCIDENTS,

BOAT MISHAPS ETC)

Morbidity

temporary/permanent

death

Moderate 6

Perception of the Project

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The respondent groups stated that the beneficial aspects of BCA project was only in

the area of employment (mainly as unskilled labour) and some welfare improvement

programmes instituted in the host communities.

Perceived adverse impacts of the project in the area include:

1. Increased gas flaring from the flow stations with its attendant ecological, human

health and socio-environmental impacts.

2. Loss of wildlife in the area due to continuous lighting (especially at night time)

from the flare stalks;

3. Reduction in games and hunting activities, a major source of household income in

the area;

4. Excessive heat flux in the area resulting from the gas flares;

5. Oil spillage from manifold, flow stations, and obsolete equipment (pipeline),

which usually destroys farmland, swamps (fishing grounds) and generally results

in the loss of biodiversity in the area

7. Increased ocular and dermal ailments in the area, especially among children and

the elderly.

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CHAPTER FIVE

5.0 CONSULTATION

5.1 General

This chapter presents the details of Consultations undertaken for the proposed

Benisede Catchment Area (BCA) Field Development Plan (FDP).

It has been recognized in Shell Petroleum Development Company of Nigeria Limited

(SPDC) that apart from being a regulatory requirement, consultation is part of good

business practice. The primary objectives of effective consultation in the Benisede

Catchment Area (BCA) Field Development Plan (FDP) are to:

Meet statutory requirement,

Identify stakeholders for the Benisede Catchment Area (BCA) Field

Development Plan (FDP),

Notify the relevant stakeholders about the Benisede Catchment Area (BCA)

Field Development Plan (FDP),

Explain to both Government and host communities the proposed project

activities/operations and to ensure exchange of information that will facilitate

good working relations, and

Identify issues and concerns of the residents at an early stage to avoid

unnecessary public opposition of the Benisede Catchment Area (BCA) Field

Development Plan (FDP).

5.2 Consultation for the BCA FDP project

Public consultation process in relation to the Benisede Catchment Area (BCA) Field

Development Project was implemented by two agents. These are:

(a) The proponent, SPDC and

(b) The EIA/ SIA/HIA consultants.

5.2.1 Consultations by the Proponent

In SPDC, consultation process is on-going and will be implemented throughout the

life cycle of the project. For the Benisede Catchment Area (BCA) Field Development

Project, SPDC has consulted with the regulators and the host communities.

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All the relevant Governmental and non-governmental organizations, agencies, and

communities have been and will continue to be consulted by SPDC as the Benisede

Catchment Area (BCA) Field Development Project progresses in line with statutory

requirements and SPDC policy.

5.2.2 Field Consultations by EIA/ SIA/HIA Consultants

Field consultations by EIA/ SIA/HIA consultants for the Benisede Catchment Area

(BCA) Field Development Project were carried out by administering questionnaires

and through interviews. (See questionnaires in Appendix V)

5.3 Identified Stakeholders for the BCA FDP

Apart from the proponent and all her operators, the underlisted stakeholders of the

Benisede Catchment Area (BCA) Field Development Project have been identified.

They are:

The Regulators (Federal Ministry of Environment, Department of Petroleum

Resources, Ministries of Environment/Environmental Protection Agency or

Body in Bayelsa and Delta States, etc),

Host Communities of the Benisede Catchment Area (BCA) Field

Development Project

5.4 Consultation with Regulators for the BCA FDP

As part of the consultation with regulators for the BCA FDP project, a detailed project

proposal/terms of reference (TOR) has been submitted to Federal Ministry of

Environment and Department of Petroleum Resources (see Appendix V). This

process, which, registers the proponent’s intention with the regulators to embark on

the proposed BCA FDP project was followed by Site Verification visits to ensure that

the consultation is done prior to the commencement of the project.

5.5 Consultation with Host Communities for the BCA FDP

Scoping workshop report for the project and Minutes of meetings are provided in

Appendix V.

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5.6 Community Concerns about the BCA FDP

Some of the concerns and expectation of the residents of BCA FDP area are

listed below.

Employment of the indigenes into the oil companies

Provision of basic amenities like pipe-borne water and electricity

Provision of Schools and award of scholarships to indigenes

Provision of micro-credit facilities to boost economic activities in the

communities

Construction of good road network to enhance evacuation of agricultural

produce and fish products to the market in town

Provision of marine vessels to enhance local transportation within the riverine

communities

Construction of Landing jetties and shoreline protection facilities to prevent

shoreline erosion.

5.7 Community Assistance/Community Development Projects

The BCA communities have all benefited from SPDC Community

Assistance/Community Development (CA/CD) programmes. A good number of

social infrastructural facilities were provided to the communities such as: Post

primary school and University Scholarship to deserving students annually. In

anticipation of the proposed Field development projects, the Southern Swamp AGG,

Pipeline and Flowline construction work, etc., SPDC in 2001 signed a 5-year

development plan Memorandum Of Understanding (MOU) with Ojobo and

Peretorugbene communities respectively. In the signed MOUs is a plan for inter-

dependency electricity project for the two communities. It is hoped that when these

projects are completed, disruption to SPDC operations in the area will be minimised.

Similar MOUs are being developed for the Amabulou Federated communities. There

is also a development plan already put in place, as well as annual CD plan for some of

the pipeline and gateway communities.

SPDC Community Assistance (CA)/Community Development (CD) projects and their

current status in the BCA FDP project Area are presented in Chapter 8 (Tables 8.4

and 8.5).

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CHAPTER SIX

6.0 POTENTIAL IMPACT ASSESSMENT

6.1 General

Impact assessment is required for all major public and private projects that might

significantly affect the quality of the environment. It is intended to provide reasoned

predictions of the possible consequences of policy decisions and thus, to permit wiser

choices among alternative courses of action.

In pursuance of its policy on the environment and in compliance with relevant

national and international laws and conventions, acceptable industry standards, SPDC

has embarked on this impact assessment prior to the commencement of the project.

The study is intended to predict, identify, interpret and communicate the impacts of

the various phases of the project on the environment. This Chapter however evaluates

the potential impacts of the various project activities of the proposed Benisede

Catchment Area Field Development Plan project on the environment. The stepwise

approach adapted for the assessment is illustrated in Fig. 6.1.

6.2 Principles of Impact Prediction and Evaluation

Whatever the impact and whatever specific technique is used to analyse it, prediction and

evaluation should be based on a sound methodological framework, which covers;

The overall prediction and evaluation process

Choice of prediction technique

Criteria for evaluating significance

The design of mitigation measures

Indirect impacts, long range impacts and uncertainty

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Identification

of Project

Activities and

Process [using

knowledge of

project/technic

al description]

Assessment of

Interaction of

Project

Activities with

environmental

components

[using opinion

of experts and

stakeholders and

design

assumptions.]

Evaluation of

Impact Significance

Comparative

analysis

Evaluation of

importance of

ecosystem.

Ecosystem

vulnerability

juxtaposed with

project activities.

Weigh Significant

Impacts Against

Existing

Regulations.

DPR

FMENV

International

Conventions.

Natural

concentrations

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6.3 Impact Assessment Methodology

There are several approaches and techniques developed for evaluating potential

impacts of any project on the environment. Some of which were developed in the

early 1970s and lean heavily upon approaches used in other spheres of environmental

management (Wathern, 1986). The Overlays techniques (McHarg, 1968); Leopold

matrix (Leopold et al., 1971); Battelle Environmental Evaluation System (Dee et al.,

1973) and Peterson Matrix (Peterson et al., 1974) are among the most widely used

methods employed for impact assessment.

The overlay technique

The overlay technique uses a series of transparencies to identify, predict, assign

relative significance to, and communicates impacts in a geographical area. In this

method, the study area is sub-divided into convenient geographical units, based on

uniformly spaced grid points, topographic features or differing land uses. Within each

unit, the assessor collects information on environmental factors, through aerial

photography, topography, land inventory maps, field observations, public meetings

and discussions. The concerns are assembled into a set of factors, and used to draw a

regional map. By a series of overlays the land-use suitability, action compatibility,

and engineering feasibility are evaluated visually, in order that the best combination

may be identified.

Leopold Matrix

Leopold et al (1971) were the first to suggest the use of a matrix method for impact

assessment. This method is useful as it reflects the fact that impacts result from

interaction of development activities and the environment. Thus, Leopold Matrix is a

comprehensive checklist designed for the assessment of impacts associated with

almost any type of construction project. One hundred possible project actions are

listed on one axis, eighty-eight human and natural environmental elements on the

other. The Leopold matrix is also used to present the results of an appraisal. Numbers

representing magnitude and significance, expressed on a 10-point scale, are included

in each cell indicating where a likely impact is anticipated. Positive and negative

impacts are identified with “+” or “-” sign, respectively.

Battelle Environmental Evaluation System

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The Battelle Environmental Evaluation system involves the separation of human

concerns into four categories namely, ecology, physical/chemical, aesthetics and

socio-economics. The method translates the state of individual environmental

parameters into arbitrary, environmental quality indices all expressed in the same

scale. For each component, the Battelle system develops an index of environmental

quality, normalised to a scale ranging from 0 to 1, using a value-function method.

Each impact indicator is given as the difference in environmental quality between the

states with and those without actions. Environmental quality scores are multiplied by

the appropriate weightings and added to give a total score of environmental quality

for each option under consideration.

Peterson Matrix

Peterson Matrix is a modified version of Leopold matrix, adopted for the screening

and scoping exercise of this project. This matrix relies directly on the multiplication

properties of matrices. An ordinal scale is used to evaluate individual impacts by a

team of assessors, and separate matrix layers are produced for physical and human

impacts. The matrices are also multiplied to find the effect of the casual elements on

human environment while the resulting product is weighed according to the

significance of the human impact.

6.4. Screening and Scoping of the Potential Impacts

It has become necessary to undertake an early and open process for determining the scope of

issues to be addressed and for identifying the significant issues relating to a proposed action.

It is important that the effective screening of actions takes place in all environmental

assessment systems. Without it, unnecessarily large numbers of actions would be assessed

and some actions with significant adverse impacts may be overlooked. The determination of

whether or not an environmental assessment is to be prepared for a particular action should

hinge upon the likely significance of its environmental impacts. Lee, (2000), identified two

broad approaches to the identification of such action and they include:

The compilation of list of actions, accompanying thresholds and criteria (which

may include locational characteristics) to help in determining which actions

should be assessed, and

SPDC Chapter Six


The establishment of a procedure (which may include the preparation of a

preliminary or intermediate environmental assessment report) for the case by case

(discretionary) determination of which actions should be assessed.

To undertake this process, an assessment of the environmental impacts of action should be

made. For this project, the likely significant potential impacts of the proposed development

project on the swamp ecosystem of Benisede Catchment Area fields are derived from the

following:

Knowledge of the project activities, equipment types and layout of the project

facilities;

The status of the baseline of the environment;

Findings of other EIA studies on similar projects;

Experience on similar projects and

Series of expert group discussions and meetings.

The criteria applied for predicting the impacts for this project on the swamp

environment were:

Magnitude -- probable severity.

Prevalence -- likely extent of the impact.

Duration and frequency -- intermittent, short term, long term.

Risk -- probability of serious effects.

Importance -- value attached to the undisturbed project environment.

The screening of the project activities indicate that construction of wells, flowstation,

transportation of materials to site during construction phase, presence of infrastructure

during operational phase pose a threat to the biotic and abiotic components. Most of

the adverse effect will come from construction phase involving the drilling of wells,

dredging, flowstation upgrade, and laying of flowlines. These impacts are expected to

be short-term and shall cease with the completion of the construction phase. Impacts

from operational phase are expected to be long-term.

The social components are expected to have beneficial impacts like the recruitment of

labour force, which will increase income and inject a sizeable amount of cash into the

Nigerian economy.

SPDC Chapter Six


The main environmental components that shall be significantly impacted are water

quality, ecology, fisheries, wildlife fauna, health and safety of host communities and

workers. The impact indicators are defined and adopted so as to identify potential

environmental impacts. Impact indicators are the easily observable environmental

components, which readily indicate changes. The impact indicators used for this

study are presented in Table 6.1

TABLE 6.1 ENVIRONMENTAL COMPONENTS AND POTENTIAL IMPACT

INDICATORS

Environmental components

Impact Indicators

Climate Temperature, Rainfall, Relative Humidity

Air Quality Particulate, NOx, SOx, CO2, CO, VOC

Soil Soil type and structure, physico-chemical and

microbiological characteristic

Surface water Characteristics Dissolved and suspended Solids; Turbidity,

Euthrophication and Toxicity

Ecology / Hydrobiology Species diversity, Abundance, Productivity, Yield.

Sediment Characteristics pH, Heavy metal concentration,

The scoping of potential impacts involves identifications of interactions between

project activities and environmental impact indicators. This stage of the impact

assessment process simply qualifies impacts as beneficial or as adverse. Ranking of

the potential impacts at this stage is done on a scale of 1 to 5 and the interpretations

are as follows:

1 = Very low impact (insignificant)

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2 = Low impact (insignificant)

3 = Moderate impact (significant)

4 = High impact (significant)

5 = Very high impact (significant)

The ranking, relative to recovery period was as follow:

Transient A few hours to some days

Short term ≤ 6 months,

Medium-term 6 – 12 months

Long term >12 months

Very long/Permanent ≤ 5 years

A checklist of key project activities and description of the potential and associated

impacts identified for the various activities is presented in Table 6.2.

SPDC Chapter Six


Table 6.2: Potential and Associated Impact Identification Checklist

PROJECT

ACTIVITY

GENERAL DESCRIPTION OF IMPACTS

NATURE OF IMPACTS

Adverse Beneficial Short-term Long-term

Mobilization and other

logistic demands

Interference with other public and private water transport

activities and alternative uses of the mob. / demob. route(s)

and drilling sites.

X

X

Physical disturbance of Bomadi and Brass Creeks by the

flowstation anchors and chains.

X X

Emission of atmospheric pollutants from exhausts. X X

Reduction in aesthetic and recreational value of drilling

sites.

X X

Pollution of surface water by anti-fouling chemicals used

to coat metal surface to discourage growth of algae and

corrosion.

X

X

Site Preparation and

Drilling

Dredging

Unintentional

discharges

Employment of

locals as skilled

and/or unskilled

labour.

Discharge of

drill cuttings,

sewage, other

wastes, gaseous

emission and noise

Increased turbidity of surface water, dislodging of aquatic

organisms and disruption of fish spawning.

X

X

Increase in biological and chemical toxicity of surface

water from discharged chemicals, wastes and materials

including spent mud, oily wastewater, sewage, cooling

water and additives etc.

X

X

Pollution of surface water from spilled hydrocarbons that

may occur as a result of sabotage, well blow-outs, flowline

ruptures, etc.

X

X

Destruction of benthic flora and fauna by unintentional

dumping of drilling mud and cuttings.

X

X

Increased income and livelihood

X

X

Localised increase in baseline concentrations of surface

water physico-chemical parameters from routine discharge

of drill cuttings, chemicals, treated sewage, deck drainage,

etc.

X

X

Localised dumping of drilling mud and cuttings in the

Bomadi and Brass Creeks.

X

X

SPDC Chapter Six


PROJECT

ACTIVITY

GENERAL DESCRIPTION OF IMPACTS

NATURE OF IMPACTS

Adverse Beneficial Short-term Long-term

Operations

Oil spills

Localised increase in ambient concentrations of air

pollutants from the exhausts of fuel combustion engines

and well testing flaring.

X

X

Possible collision of boats during operation.

X

X

Noise (on-site) from the use of operations engines and

motors.

X

X

Increased national revenue from oil and gas exploitation X X

Employment of locals and consequent increase in business

activities in the area

X

X

Community Development Programmes X X

Oiling of surface water. This will reduce light penetration

and thus overall productivity of the ecosystem.

X

X

Oiling of surface water can also reduce dissolved oxygen

levels and cause oxygen starvation and death of aquatic

organisms.

X

X

Spilled oil may emulsify and eventually dissolve into

surface water to increase its toxicity. This may lead to the

death of the less resistant/adaptable aquatic organisms and

dominance of the more resistance ones.

X

X

Decommissioning and

abandonment

Collision of boats with abandoned wellhead structures. X X

Permanent obstruction of Creek-bottom with permanent

structures such as the wellhead structures.

X

X

Hydrocarbon leak from abandoned wellhead and flowlines. X X

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6.5 Potential Impact Evaluation

The purpose for this evaluation is to assign relative significance to the predicted

impacts associated with this project and to also determine the priority order in which

the potential impacts are to be avoided or mitigated. This involves the computation of

the potential impact of the project activities on the recipient environment. The first

step is to determine the magnitude of impact and thereafter evaluate the importance of

the impact relative to its ecological and social values. The evaluation of the degree of

alteration to natural conditions due to the project activities were carried out using a

modified Leopold and Peterson matrices that permits scaling and direct transformation

of impact magnitude and importance into potential impact significance (Peterson et

al., 1974); (See Table 6.3).

The significance of impacts are linked to the following elements;

Effect of project action on wildlife

Ecosystem sensitivity, biodiversity and carrying capacity

Viability of local species population

Rare and endangered species

Duration

Demand on transport

Recreational values of the prospect

In this method, project activities are assigned to columns, while environmental

components and characteristics are indicated in rows in the matrices. Then the project

activities are interacted with the environmental components and characteristics using

mathematically weighted values for each activity with respect to the environmental

components and characteristics. The mathematical weighting was done based on the

magnitude and importance of potential impacts of the project activity on the

environment. Where possible, quantification of impacts has been undertaken. In some

cases, systems of weighting together the quantitative scoring of rankings of various

effects have been adopted, but there is no general consensus as to the relative values.

The value assigned to each cell in the matrices is in the form “x (y)”: where “x”

denotes the magnitude and “y” the importance of the impact. Positive (+) and

negative (-) signs were used to represent beneficial and adverse impacts respectively.

The effect of any particular activity across all environmental components and

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characteristics are assigned columns, while the potential impacts of all project

activities on a particular environmental component or characteristic are assigned to

rows. A quantitative evaluation of the impacts of the BCA FDP drilling project on the

environment are shown in Table 6.3.

Summary of Potential Impact Evaluation

The evaluation of the impact of the Benisede Catchment Area FDP project activities

on the various environmental components is presented in Table 6.3. The proposed

project activities, which could adversely impact the environment of the project area,

are, transportation of equipment and materials, construction, (flowline laying,

trenching, backfilling, hydrotesting, dredging, drilling, etc.), and abandonment.

The adverse environmental impacts, which are likely to occur mostly at the

construction phase (site preparation/drilling) of the BCA FDP project, shall be short-

term. Consequently, these adverse impacts will be localized and transient. However,

mitigation measures have been proffered, to eliminate or reduce these impacts to

tolerable levels . Overall, the beneficial impact from the BCA FDP project shall be

long-term. These beneficial impacts will result from increased business activities in

the area, employment for skilled and unskilled labourers and community development

activities.

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Table 6.3: Impact Evaluation Matrix for BCA FDP

6.6 Detailed Description of Potential Impacts

Project Activities

Environmental

Component (x)

Aggre

gate

Rati

ng

of

Eco

logic

al

Com

pon

ents

(y)

Sit

e M

obil

izat

ion/

oth

er l

ogis

tic

nee

ds

Con

stru

ctio

n a

nd

Inst

alla

tion

/Flo

wli

ne

layin

g

Dre

dgin

g

Dri

llin

g

Was

tes

dis

posa

l

Oper

atio

ns

/

Mai

nte

nan

ce

Mat

eria

ls

Tra

nsp

ort

Acc

iden

tal

spil

l &

Lea

ks

Gas

eous

Em

issi

on/F

lare

s

Dem

obil

izat

ion

Air Quality

Particulates

Acid gases (SOx, NOx, NH3) 2

2

-2

-2

-3

-3

-2

-2

-2

-3

-2

-1

-1

-3

-3

COx 2 -1 -2 -3 -3 -2 -3

VOC 2 -2 -2 -3

Surface water Quality

Turbidity and solids

Temperature 4

4

-1

-3

-2

-3

-3

-3

-4

-2

-2

-2

-2

-4

-1

-1

Oil and Grease 4 -1 -3 -3 -4 -3 -1 -4 -1

Biochemical Parameters 4 -1 -2 -3 -3 -3 -1 -4

Groundwater Quality

Turbidity and solids

Oil and Grease

Biochemical Parameters

4

4

4

-1

-1

-2

-2

-1

-2

-1

-1

-2

Aquatic Ecology

Diversity & abundance 4 -1 -1 -2 -1 -1 -2 -1 -3 -1

Productivity 4 -1 -1 -3 -1 -2 -2 -1 -4 -1

Catch and Yield 4 -1 -1 -2 -1 -2 -2 -1 -4 -1

Vegetation/

Terrestrial Ecology

Diversity & abundance 5 -1 -2 -3 -2 -2

Forest Resources 5 -1 -2 -3 -2 -1

Habitat 5 -2 -2 -4 -3 -2

Productivity 5 -1 -2 -4 -2 -2

Soils/Landuse

Soil fertility / Productivity 2 -1 -3 -2 -1 -3

Soil Erosion 2 -3 -2 -3 -1

Land take 1 -4 -3 -2 -1

Sediment Characteristics

Physico-chemistry

Productivity 3

4

-1

-2

-2

-3

-1

-1

-1

-3

-1

-2

-3

Noise/Vibration

On-site

Off-site

3

3

-1

-1

-2

-2

-2 -2

-2

-2

-1

-2

-2

-1

-1

SPDC Chapter Six


6.6.1 Rig Mobilisation

The drilling campaign will involve several movements in the course of the drilling

project. There shall also be the need for spread mooring with chain, standard wire

cable and anchor for each leg of the rig. These operations and activities are likely to

have the following impacts:

Discharges and emissions

Creek disturbance and interference due to anchoring and movement;

Fisheries interaction; and

Boat navigation interaction.

The process of mobilisation and movement of construction materials to site shall exert

stress on the creeks resulting in the suspension of sediments. This could lead to

destruction of habitats/communities of benthic organisms. Flowstation positioning

shall also cause disturbance to Creek-bed through increase in suspended solids,

smothering/burial of fauna. However, this impact is considered insignificant, as

recovery time is usually short.

The physical presence of the wellheads, flowstation and other facilities may be an

obstacle to fishing and navigational routes within the area. Nevertheless, this impact

is not significant because of the relatively small area these facilities will occupy.

6.6.2 Drilling

The primary sources of impact associated with the drilling operations are related to

waste disposal. Thus in the course of this project, the following category of liquid

effluent, and other potential release may affect the water quality of the block. These

includes:

Drilling fluid and cuttings;

Grey water from house-showers or galley

Black water from sewage system

Accidental releases (such as diesel fuel, crude oil)

6.6.2.1 Drilling fluid and cuttings;

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The main activities, which may result in environmental impacts, include those

associated with drilling mud and the disposal of drilling cuttings. SPDC consider the

need for clean and unpolluted environment in their operational areas and therefore

propose to use water based mud (WBM) and pseudo – oil based mud (POBM) in their

proposed drilling programmes. WBM are widely viewed by the industry and

regulators as being sufficiently non-toxic as to have special disposal requirements.

According to the UNEP (1985) WBM and POBM discharges are not especially toxic,

being either biochemically inert or non-toxic derivatives of natural product.

The primary causes of drilling impacts are from smothering of the sediment by

discharged materials, which includes the drilling rock cuttings and the drilling mud.

While the drilling cuttings cause physical changes in the sediment characteristics, it is

the drilling mud, which causes significant chemical changes, which may have longer-

term effects. The overall impacts are related to the total tonnage of discharges, their

distribution across the seabed and the chemical characteristics of the drilling mud.

6.6.2.2 Sewage and Sanitary Wastes

This includes all sanitary waste and grey-water, that is water from showers sinks,

garbage disposal, etc. This waste will be treated in the sanitary sewage treatment unit

before disposal. This is particularly important since the well construction phase of the

project will require about 100 men on site.

6.6.2.3 Accidental Oil Spill

Accidental oil spills could have serious economic impact on coastal activities and

direct health impact on the host communities. In most cases such damage is temporary

and is caused primarily by the physical properties of oil creating nuisance and

hazardous conditions. The impact on aquatic life is compounded by toxicity and

tainting effects resulting from the chemical composition of oil, as well as by the

diversity and variability of biological systems and their sensitivity to oil pollution.

The effects of oil spills on fish larvae are even more pronounced when dispersants are

used. In addition, crude oil contamination of the water from which phytoplankton

derive nutrients will adversely affect the rate of primary production.

6.6.3 Impact due to Dredging

Dredging activities during the proposed project will result in the following impacts:

SPDC Chapter Six


Changes in water quality viz higher turbidity, reduced light penetration, stress

on photosynthetic algae including other light sensitive organisms.

Noise of dredging operations.

Offensive smell from dredged spoils.

Loss of biodiversity.

Vibrations.

Prevention of fish migrating to spawning grounds.

Destruction of spawning grounds by the removal of habits.

Possible release of locked up nutrients by the agitation and overflow of

dredged spoil.

Possibility of subsoil failure.

Possible depletion of local fish communities.

River bank draw down i.e. movement of materials riverwards due to removal

of sediments.

6.6.4 Impact due to Flowline Installation:

Flowlines will be laid across the Creek-bed resulting in localised bed disturbance.

Such disturbances may take the form of loss of benthic organisms through smothering

or burial, interference with fishing activities, navigational impacts, suspended solids,

anchor damage to the creek-bed, etc. The precise width of sediment disruption is

unclear and varies according to the type of substrate and depth of water.

6.6.5 Gaseous Emissions

Atmospheric or gaseous emissions anticipated during the project will emanate from

fuel powered boats, electrical generators, vented gases (during testing), flared gases

from well testing/well clean-up, helicopter, and fugitive emissions, e.g., leaks from

components such as valves and connectors. The emissions are dependent upon the

fuel use of boats, generators, etc.

6.6.6 Impact on Fishing

Commercial Fishing:

SPDC Chapter Six


The presence of utility boats on the creeks during transportation of equipment and

materials would obstruct the movement of fishing boats. In addition, the high turbidity

of the surface waters that is likely to result during drilling and other construction

activities would reduce dissolved oxygen, which is crucial for fish yield. This is likely

to have limited temporary interference with commercial fishing activities in the area.

There may also be limited temporary interference from periodic visits to the

flowstation by supply vessels.

6.6.7 Impact due to Well blow-out:

A blow out is one potential impact of drilling operations that must certainly be

avoided because such an occurrence, which results in the sudden release of pressure,

could be devastating. Well blowouts or explosions are associated with geological

formations that are characterised by abnormal formation pressure. Oil, saline water,

and volatile organic compounds (VOC) could be emitted into the atmosphere. The

subsequent explosion could emit dangerous gases into the air, as well as oil and

chemicals into the swamp environment, which could also contaminate soil and

sediments.

6.6.8 Beneficial impacts

The execution of the field development plan activities will provide employment

opportunities for unemployed Nigerians. The number of persons to be employed shall

however, depend on the work force needed and the proportion of the work activities.

Provision of employment during the project execution will have additional benefit

augmenting household incomes and thus improving living standards. Moreover, the

Benisede Catchment Area FDP project is expected to pave way for the further

development of the oil resources in the Southern Swamp Production Area. This will

bring about associated financial benefits to SPDC and Nigeria.

6.7 RISK ASSESSMENT

Risk assessment according to Wathern (1986) stresses formal quantification of

probability and uncertainty. Thus a study that provides quantitative measures of risk

levels, where risk refers to the possibility of uncertain, adverse consequences, most

fundamental estimates of possible health and other consequences. A risk assessment

SPDC Chapter Six


typically includes a determination of the types of hazard posed, together with

estimates of probability of their occurrence. It also includes the population at risk of

exposure and the ensuing adverse consequences (Conservation Foundation 1984).

6.7.1 Assessment of Hazards

Assessment of HSE risk associated with identified hazards in SSA operations and

activities are carried out regularly in line with corporate procedure. All hazards,

effects and aspects identified in the HEMP process shall be ranked in terms of risk.

For the qualitative portrayal of risk and screening criteria for potential incidents and

chronic effects, the concept of the risk matrix (Table 6.4) shall be used.

The assessments (hazard register and aspect tables/registers) are updated at specified

intervals defined in the HSE Case. The assessments shall be reviewed when

circumstances change as part of the change control procedure.

Table 6.4: SPDC HSE Risk Matrix

CONSEQUENCE PROBABILITY

A B C D E

Severity

People

Assets

Environ-

ment

Reputation

Never

heard of

incident in

industry

Incident

has

occurred in

oil industry

Incident

has

occurred in

SPDC

Happens

several

times per

year in

SPDC

Happens

several

times per

year in

District

0 No injury No damage No effect No impact

1 Slight

Injury

Slight

damage

Slight effect Slight

impact

Low

2 Minor

Injury

Minor

damage

Minor

effect

Limited

impact

Risk

3 Major Injury

Localised damage

Localised effect

Considerable impact

Medium

4 Single

Fatality

Major

damage

Major effect National

impact

Risk High

5 Multiple

Fatalities

Extensive

damage

Massive

effect

Internationa

l impact

Risk

6.7.2 Project Risk Management

In order to continuously address the risks associated with this project a risk register

was set up and routinely updated. Risk events affecting all aspects of the project were

SPDC Chapter Six


identified i.e., wells, reservoir, facilities, communities, commerce, organisation and

politics.

It is recommended that the register is kept alive through out the project

implementation phase.

The BCA FDP Project shall be carried out within the framework of SPDC Corporate

policy. The Hazards and Effects Management Process (HEMP) activities will ensure and

demonstrate the reduction of risks to ALARP levels.

6.7.3 Health, Safety and Environmental Management System in BCA.

The SPDC HSE Policy requires a systematic approach to HSE management designed

to ensure compliance with the law and to achieve continuous performance

improvement in the Benisede Catchment Area.

The HSE management system as operated in Benisede Catchment Area facilitates the

management of HSE hazards and effects associated with its business. This includes

the organisational structure, planning activities, responsibilities, standards,

documentation and resources for developing, implementing, achieving, reviewing and

maintaining the company's HSE Policy and meeting it's stated objectives.

The system concentrates on critical activities and ensures that they are properly

controlled and that measurements are made and reported so as to enable monitoring of

overall performance and identification of areas for improvement. This management

system provides a structured process for the achievement of continual improvement.

The Benisede team is currently working and improving the system to bring about

improvement in HSE performance. This also includes for behaviour and attitudinal

change to support compliance with the system.

In line with the EP Position on Global Environment Standards, the Benisede

Catchment Area operations and facilities have implemented an HSE MS (documented

HSE Case) and the environmental component of the HSE MS has been certified to

ISO 14001 standard.

Other environmental targets set by the Shell Group as contained in the Group

Minimum Environmental Expectations (MEE) are being implemented in the Benisede

Catchment Area. However, two of the MEE items, Elimination of routine gas flaring

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and Elimination of Hard CFC with target dates of 2008 and 2005 respectively, are

pending for the field.

Currently H, S and E in Benisede Catchment Area operations is managed within an

integrated HSE Management System, but in the longer term, it is expected that

Management Systems, which encompass all aspects of the business, will become the

norm.

6.8 Modelling

6.8.1 Air Quality Modelling

Meteorological Conditions

The meteorological conditions used for this study are based on actual field data and

available historical data for the project area. Ambient air conditions most conducive

to primary impacts are:

Mixing height of which is low and persistent

Wind direction that is persistent towards sensitive receptors (southwesterly in this

case)

Wind speed which is calm to low

Slightly unstable stability (class C)

Emissions

The summary of daily emissions from the proposed flowstation per day is as indicated

in the Table 6.5.

Table 6.5: Summary of emissions from the proposed flowstation

Sources

Emissions (Tonnes/day)

CO2 CO NO2 N2O SO2 CH4 VOC

Flaring 1108.3 4.7 0.6 0.0 0.0 14.9 6.4

Fugitives &

Miscellaneous

- - - - - 24.9 10.7

Internal

Combustion

234.1 0.2 0.6 0.0 0.0 0.0 0.0

SPDC Chapter Six


Engines

Total 1342.4 4.9 1.2 0.0 0.0 39.8 17.0

Flare Emission Dispersion Model

The dispersion of air-borne effluent from the proposed flowstation flare points in the

Benisede project was predicted using SCREEN Model - Version 1.1. This model was

applied in performing single source, short-term gaseous effluent dispersion including

maximum ground-level concentrations and the distance to the maximum ground level

concentrations, incorporating the effect of downwash on the maximum concentrations

for both the near wake and far wake regions.

The Flare Emission Dispersion Model simulates events of a prolonged shot-down of

the CPF, which will entail the flaring of gases locally, via 16inch vertical or

horizontal flare stacks at the Flowstation.

The modelling calculation was based on engineering/design specifications,

hydrocarbon gas composition and meteorological characteristics of the area. These

include basic flare stack diameter of 0.4064m (16 inches), wind speed of 10ms-1

,

radiation level of 3.15 KW/m2, for the stack and maximum predicted flow of

16.5mmscfd and a Rich Gas composition of molecular weight of 19.45 was used. The

effective flare stack height of 30.0m was applied for the vertical flare stacks

The simulation result indicates that the final stable plume heights of 33.1m for the

flare stack and would occur at a distance of 1500 to 2000m from the stack. From the

simulation (also presented graphically in Figure 6.2, it can be inferred that the

maximum concentration of flare emissions from the stack would be observed 200 and

500m from the flare. The maximum observable concentration of acidic gases from

the flare stack in the prevailing wind direction is 680 - 520mg/m3. This result implies

that monitoring stations should be established 200 to 500m from the flare stack along

the prevailing wind direction.

SPDC Chapter Six


SPDC Chapter Six


Fig 6.2 : Benisede Catchment Area Flare Emission Dispersion Model

0

100

200

300

400

500

600

700

800

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30

Distance from Flare (x 100m)

Conc.

(m

q/m

3)

SPDC Chapter Seven

EIA of Benisede Catchment Area FDP Phase 2 June, 2005 164

of 253

The estimated maximum concentrations for 1-hour, 3-hour, 8-hour and 24-hour

averaging time for the proposed flare stack in the project area is as shown in the table

below.

Table 6.6: Maximum Concentrations for Selected Periods (hours)

The above results imply that the predicted hourly maximum emission concentrations

from the proposed project area flare stack would be within FMENV regulatory limits of

200 - 9000 mg/m3

for acid gases from stationary sources (FEPA, 1991). This is mainly

due to SPDC’s choice for appropriate design specifications and stack height of 30m

which comply with “good engineering practice” (GEP) with no downwash effects.

The emission from the project area flare stack will not have adverse significant potential

environmental impacts on the vegetation, soil, water and air quality of the area as the flaring

will be sparing and intermittent.

6.8.2 Surface Water Quality Modelling

Methodology

The depths across Bomadi and Brass creeks, and some creeklets at the designated

sampling stations were determined using a Sounder. The width of the creeks/creeklets

was measured and plotted directly on the topographical (Base) map of the Project Area

showing Creeks and Creeklets and existing/planned facilities

Input Data

The flow rate (current), width and depths across the creeks/creeklets at each of the

sampling stations in the proposed project area is shown in Table 6.7. The flow rate,

width, depths, aquatic temperatures (generally very high, ranging from 21.8° to 33.4o C,

air temperature, water transparency (generally low with an average depth ranging from

40.7 to 46 cm), turbidity (high ranging from 2.1 to 56.0 NTU). The surface water flow

Period (hrs) Concentration

1 hour 680.9mg/m3

3 hour 612.8mg/m3

8 hour 476.6mg/m3

24 hour 272.4mg/m3

SPDC Chapter Seven

EIA of Benisede Catchment Area FDP Phase 2 June, 2005 165 of

253

rates ranged from 4.45 to 23.65cm/sec while the depth and width of the rivers and creeks

range from 4.00 - 14.50 and 30.0 - 160m respectively.

Table 6.7: Flow rate (current), Width and Depths across Creeks and Creeklets

Sampling

station

Width (m) Depths (m) Flow rate

(cm/sec)

Edge Middle Edge

W1 125 4.0 9.0 4.2 19.13

W2 67 4.0 9.0 5.0 19.42

W3 52 2.5 4.0 3.0 4.76

W4 140 4.0 13.5 5.0 17.49

W5 80 4.5 7.0 3.2 12.68

W6 85 3.5 12.5 5.6 20.15

W7 50 2.0 4.0 2.5 10.06

W8 120 5.0 13.5 6.0 16.59

W9 120 4.5 14.0 4.0 16.02

W10 135 6.8 14.5 5.5 23.54

W11 30 2.5 6.5 3.0 10.28

W12 90 3.0 9.0 5.2 14.37

Results

Oil slick on water bodies in the study areas will form patches of thick oil and sheen in

the downwind portion of the slick. During the spreading and transport of the slick,

spilled oil will be subjected to further emulsification, evaporation to the atmosphere,

dispersion and sedimentation into the waters (Fig. 6.3). Slick will therefore spread and

grow in area, but its thickness will decrease. The activities will be enhanced due to the

corresponding high water and air temperatures in the area. Over a 100C temperature

range, the density of waters in the study areas will change by 0.25% whereas oil density

will change by 0.5. Therefore oil which barely floats during the day and may submerge

(sedimentation) as the temperature falls at night due to its greater relative increase in

density may resurface later in warmer waters. In areas laden with suspended solids,

sedimentation will also occur.

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Figure 6.3: Oil Spill Fate on Water Surfaces within Benisede

6.8.3 Ground Water Modelling

Regional Geology

The study area (BCA) is located in the Niger Delta. The Niger Delta is underlain at great

depth by the crystalline Basement. Structural analysis of the sediment fill shows that the

Delta is made up of various fault blocks. The development of the Delta has depended

upon the balance between the rate of sedimentation and the rate of subsidence. From the

Late Cretaceous, the Basement underlying the Niger Delta started subsiding. Around the

transition zone of the basaltic, oceanic crust to the granitic, continental crust, the crust

broke up in many fault blocks. The fault blocks have shown an ongoing subsidence,

while the troughs were filled up with marine, paralic and continental sediments.

The study area is located in the south-westerly extension of the Benue Trough. From

Eocene onwards, a global regression caused progradation of the Niger Delta over some

200 km distance and the present day coastal zone stretches over some 300 km.

Progradation of barrier complexes was periodically interrupted by global sea-level rises,

eleven of which formed delta-wide marine marker shales.

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Lithostratigraphy

The sediments of the Niger Delta, which underlie the surficial Quaternary deposits, are

broadly divided into three main lithostratigraphic units. These are in increasing age and

depth:

• The Benin Formation. This is the youngest formation and consists of massive

continental / fluvial sands and gravels. The Benin Formation is the continental, delta-

top formation.

• The Agbada Formation. The Agbada Formation comprises shallow marine delta-front

sediments.

• The basal Akata Formation. The oldest of the three formations, comprising shales,

silts and clays. The Akata Formation is a deep marine pro-delta unit.

(Reijers, et al, 1997; Adesida, et al, 1997).

The study area is located between the Chain fault zone and the Charcot fault zone, the

roughly north-east to south-west running fault zones which form the boundaries of the

deepest part of the Niger Delta Basin (Reijers, 1994). In this part of the Niger Delta

Basin, the greatest depths to the Basement are found. Around the study area, the base

of the Akata Formation is found at a depth of over 12,000 m deep. The Akata

Formation is approximately 6,000 m thick. The overlying Agbada Formation is

approximately 4,000 m thick. The Benin Formation reaches its greatest thickness of

approximately 2,000 m in the centre of the trough. The Benin Formation deposits are

grading downwards into, or lie unconformably the Agbada Formation

(Reijers, 1994).

The significant formations for the hydrogeology of the study area are the Benin

Formation and the Surficial Deposits:

The Benin Formation

The Benin Formation extends across the whole Niger delta and beyond the present

coastline. It consists mainly of sands, with shale and gravel intercalations, fluvial

distributary channels, marshes and swamps (Reijers, 1997). The sands are essentially

fresh water bearing and form the main aquifer complex. Due to the stratified nature of

the Benin Formation, with many clay/shale intercalations, this water bearing unit can be

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sub-divided in numerous aquifers. In the lower delta, the Benin Formation is covered by

swamp deposits and abandoned beach ridges.

The Surficial deposits

The Quaternary delta-top deposits in the lower delta show a clear zoning according to

their depositional environment. Running from approximately 50 km to the north-east of

the study area to the south-west the following sequence of surficial deposits can be

distinguished as follows:

Late Pleistocene -

Early Holocene

Sombreiro-Warri Deltaic Plain Characterised by dry land

with abundant swamp zones.

Holocene - Recent Lower Deltaic Plain Mangrove Swamps

Methodology

Two Groundwater Modelling Systems (GMS) software’s (MODFLOW and MOPATH) were

used interactively for the simulation of groundwater flow and impact simulation in the

Benisede Catchment Area. MODFLOW is the most widely used 3D groundwater flow model.

MODFLOW can represent the effects of wells, rivers, streams, drains, horizontal flow barriers,

evapotranspiration, and recharge on flow systems with heterogeneous aquifer properties and

complex boundary conditions to simulate groundwater flow. Using GMS, the user can select a

single cell or a series of cells and then quickly define the hydrogeologic characteristics and/or

boundary conditions using interactive dialog boxes. In addition, a spreadsheet dialog can be

displayed, allowing the user to edit the values for each individual hydrogeologic characteristic

for the entire model. Input data were imported, and interpolated from a sparse set of scattered

data points. MODFLOW simulation approach for this study was conducted using the

conceptual approach.

MODPATH is a 3D particle tracking model that computes the path a particle takes in a steady-

state or transient flow field over a given period of time. MODPATH uses the head values and

cell-by-cell flow terms computed by MODFLOW, in addition to the soil porosity, to compute

the movement of each particle through the flow field. By specifying individual particle

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locations, MODPATH computes the location of each particle at any instance in time. Both

forward and backward tracking can be performed by MODPATH.

The other data used for the groundwater studies were stratigraphy / lithology of the subsurface

soil, hydraulic properties of the Geologic formation, hydraulic Conductivity (K), Porosity,

discharge, number and thickness of the formation, groundwater levels, depth of wells, surface

water levels, as transmissivity, leakance and coordinates of the well locations as well as flow

direction of groundwater.

Results

Stratigraphy and Groundwater Characteristics

The area is part of the Western flank of the Niger Delta. The Age is Recent. The

horizon of study, (0 - 20m) exposed by study wells is composed of coastal plain sand

which are loose and homogenous, having not undergone any amount of lithification or

diagenesis. This homogenous part is covered by a thick (0 - 5m) cover of peaty alluvial

material which completely masks the general subsurface geology.

Lithostratigraphic correlations of borehole logs shows that the formation underneath the

study area is made up of an intercallation of peat, clay and sand beds with clayey sand

lenses and sandy clay lenses varying in thickness within relatively short distances. This

observed trend in the stratigraphy is typical of a prograding deltaic environment. The

sands are very fine to medium grained

Groundwater Flow

Groundwater levels are highest around northern part of Benisede, intermediate around

south-eastern and lowest in the south west of Benisede. As indicated in Fig 6.4,

groundwater will therefore flow in the southerly direction (in the South South direction).

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FIG 6.4: GROUNDWATER FLOW DIRECTION MODEL FROM A POINT SOURCE

Impacts on Groundwater

Overburden Protective Capacity

The protective capacity of an overburden overlying aquifer within Benisede is

proportional to its hydraulic conductivity but the high clay content within the area

generally correspond with low resistivities and low hydraulic conductivities. Hence, the

protective capacity of the overburden in the area is considered being proportional to the

longitudinal unit conductance (S) defined as the ratio of the overburden thickness to its

resistivity. The sand aquifer in the area is overlain by a variably thick overburden

(topsoil/clay) whose longitudinal conductance is presented in Table 6.8.

Table 6.8: Overburden Longitudinal Conductance and the Protective Capacity

Overburden

Thickness Longitudinal

Conductance (mhos)

Protective Capacity

10.8 8.86 Excellent

21.8 23.90 Excellent

Groundwater Flow Direction

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12.6 9.97 Excellent



(Protective Capacity Rating Based on Rennet, 1976)

This indicates that the overburden capacity rating is excellent therefore, the groundwater

beneath is significantly protected from surface or near surface source of spill or

pollution. The sand aquifer may be polluted via base flow within the canals.

Soil Corrosivity

The formation of corrosion cells, which can lead to severe corrosion failure, is known to

be associated with low resistivity. Low electrical resistivities are indicative of good

electrical conducting paths arising from reduced aeration, increased electrolyte saturation

or high concentration of dissolved salts in soil. Soil resistivity can therefore be classified

in terms of the degree of soil corrosivity as shown in Table below.

Table 6.9: Classification of Soil Resistivity in Terms of the Corrosivity

Soil Resistivity (ohm-m) Soil Corrosivity

Up to 10 Very Strongly Corrosive (VSC)

10-60 Moderately Corrosive (MC)

60-180 Slightly Corrosive (SC)

180 and above Practically Non-Corrosive (PNC)

(Based on Baeckmann and Schwenk, 1975 and Agunloye, 1984)

The soil resistivity at a depth range of 1.5 - 2.5 m (normal depth of burial of oil/gas

pipes) varies from 1.1 -9.9 ohm-m. The degree of soil corrosivity based on Table 6.9

above is very strongly corrosive. Metal pipes buried within Benisede field are highly

susceptible to corrosion hence, likely to release oil to the environment.

Generally confining clays may restrict the vertical movement of oil spilled, preventing

the mixing of waters between the various aquifers. Hence, spill that occurs underground

(buried pipeline) within the clay zone will be confined. The overlaying clayey/peaty clay

will prevent direct infiltration of possible pollutants to the aquifer, however, the water

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table is shallow, and in case of leakages within areas that have been open up through the

creation of artificial canal and slots to the ground water. Impacts will occur and flow

along the direction of groundwater flow. Backward impacts will be minimal and will

take over ten years to impact up to a distance of 25m (see Fig 6.5).

FIG 6.5: IMPACT FLOW DIRECTION MODEL FROM A POINT SOURCE

Impacts Flow Direction

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CHAPTER SEVEN

7.0 MITIGATION MEASURES AND ALTERNATIVES

7.1 GENERAL

This chapter presents the mitigation measures and alternatives developed to mitigate the

significant negative impacts of all phases of the proposed BCA FDP project. Included

in this chapter are the details of the control technology and compliance with health

and safety hazards requirements including a table showing potential impacts of the

BCA FDP project with their proffered mitigation measures.

To minimize the impacts of the proposed BCA FDP project on the environmental

components of the project area, mitigation measures were proffered for the identified

potential impacts of the proposed project. The approaches to the mitigation measures

proffered included:

(i) Enhancement

(ii) Reduction

(iii) Avoidance

(iv) Compensation

7.2 PROCESS MONITORING AND CONTROL TECHNOLOGY

As a major part of mitigation measures for the BCA FDP project, the process control and

shut down systems shall be fail safe with minimum operator intervention. Consideration

shall be given to upgrading the currently designed Flowstation as part of development

modification, in line with the current company (SPDC) safety standards and

specifications.

Emergency shutdown system (ESD) checks shall be carried out at six-monthly intervals

in line with regulation (Mineral Oil Safety Regulations of 1995) to ensure integrity while

wellhead checks shall continue at the stipulated intervals.

Equipment Selection

A major determinant for rig selection is SPDC's drive to reduce impact on the

environment. A swamp drilling rig that meets the minimum requirements (as specified in

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253

chapter three, section 3.11) shall be used for this project to reduce potential impacts to as

low as reasonably practicable (ALARP).

New flowlines shall be designed to withstand maximum closed-in tubing head pressure

(CITHP) attainable in the network, according to the standard flow line design

philosophy. Old lines shall be replaced to the same standard when due, i.e. in accordance

with corporate guideline for 14-years swamp flow-line replacement.

Safeguarding Systems

Fire detection systems shall be provided in high-risk areas (transfer pumps, generators

etc.) in line with company policy. Fire hydrants and portable fire extinguishers will be

placed at strategic locations to fight small incipient fires. In the event of an

uncontrollable fire outbreak, personnel will be evacuated according to laid down

evacuation procedures.

The two levels of shut down systems (ESD and OSD) shall be maintained in the facility.

Instrumentation

Instrumentation will be designed for remote status monitoring, calibration and

configuration. Reliability of the instruments will allow for no failure maintenance.

7.3 IMPACT MITIGATION MEASURES

The proffered mitigation measures for the identified impacts are presented in Table 7.1.

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Table 7.1: Proffered mitigation measures

Project phase Project activity Environmental

aspect

Proffered mitigation measures

Site

P

re

p

a

r

at

io

n

Site clearance/

excavation

Disturbance/

interference

SPDC shall embark on community

development programmes in line with

the desires and needs of the people.

SPDC shall engage bulk unskilled

labour from the host community

Sustain open door policy to enhance

flow of information to and from host

communities to maintain existing

relationship

All logistics arrangement shall be put in

place to ensure that rig travel time is not

prolonged unnecessarily.

Land take/land

acquisition

Compensation for any land taken and

resource loss shall be adequate and in

time.

Habitat loss Vegetation clearing activities shall be

reduced to the barest minimum required

and within the immediate project

exclusion zone to accommodate

facilities and permit safe operations.

Re-vegetation of cleared areas that are

not required during operation.

Existing ROWs shall be utilized as

much as possible to avoid disturbing

habitats

Disruption/

blockage of

natural drainage

pathways

Numerous access road construction

shall be minimized as practical as

possible

Maintain and repair existing facility

access road

Erosion threat After drilling and commissioning, any

cleared areas that are no longer in use

for safe operations of facilities shall be

re-vegetated

Open up drainage systems around the

project areas.

Emission of

atmospheric

pollutants from

exhaust

SPDC shall maintain fuel combustion

engines at optimal operating conditions

to reduce emission of exhaust gases

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Dredging Increased

turbidity of

surface

water/pollution

of source of

drinking water

threat to

fishes and other

aquatic life-

forms

threat of

erosion

Dredge spoil

disposal

Alternative source of drinking water

shall be provided during the exercise.

Silt screens or other appropriate

methods shall be used to confine

suspended particulate/turbidity to small

area where settling or removal ca occur.

Dredged spoil shall be used in

construction of sedimentation basin to

reduce turbulence of the water bodies.

The dredge spoil shall be leveled to a

height of 1m

Dredging shall be systematic and

phased to allow for movement of life-

forms to safer areas.

Dredging activities shall be

monitored throughout the duration

Dredge material shall be widely

distributed in a thin layer at the disposal

site to maintain natural substrate

contours and elevations.

Well Drilling Rig

mobilization and

positioning,

installation of

jackets,

pipelines, etc

and boat

movement.

Disturbance/

interference









relationship




Noise/ vibration Exposure to high noise equipment shall

be restricted to the recommended 8-

hour a day limit

The use of earmuffs in high noise zones

and for all employees using high noise

equipment/ machinery shall be

enforced.

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Pressure on

socio-economic

facilities

SPDC shall continue to assist in

providing infrastructural facilities in the

area and in maintenance of the existing

ones.

The rig shall not be made to stop for

prolonged periods at points where the

roads are narrow or where socio-

economic activities are at peak periods,

e.g. market places

Deteriorated

landscape

Excavation and other activities that may

result in the alteration of the landscape

and condition of the land cover shall be

closely monitored.

Waste disposal Pollution of

ponds and

rivers.

SPDC shall activate her oil spill

contingency plans to minimize impacts

of oil spills and leaks on ponds and

rivers.

SPDC shall manage wastes generated in

accordance with regulatory

requirements and standard practices.

Pollution of

water by rig

coating

chemicals




rivers.




Workplace

accidents or

man overboard

[MOB]

SPDC shall enforce work procedure

[e.g. permit to work, etc] in line with

industry standards and regulatory

requirements on safety

HSE training and job hazard analysis

shall be conducted to ensure that all

staff observes safety rules at work

places.

Drill cuttings

handling.

SPDC shall treat all drill cuttings to

below 10% oil in cuttings and further

treated at the Forcados Thermal

Disorption Unit (TDU) before disposal

offshore.

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Oil leakage

resulting from

existing

pipelines rupture

due from

construction

activities




rivers.




Drill mud

handling

SPDC shall collect all drilling used

muds and treat and reuse them for

further drilling programmes.

Operation &

m

ai

nt

e

n

a

n

ce

Material

transport

Noise &

vibration

Exposure to high noise equipment shall

be restricted to the recommended 8-

hour a day limit

The use of earmuffs in high noise zones

and for all employees using high noise

equipment/ machinery shall be

enforced.

Disturbance/

interference









relationship




Spill and leaks

Pollution of

rivers and ponds




rivers.

SPDC shall implement wastes generated

in accordance with regulatory


Gas flaring

Pollutants

emission into

the air

SPDC shall maintain fuel combustion

engines at optimal operating conditions

to reduce emissions of exhaust gases.

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Waste disposal

Contamination

of soil from

disposal of

sand/oil, spent

oils etc

SPDC shall treat wastes to regulatory

limits at the Forcados TUD before

disposal

Wastes pits constructed for collection of

waste shall meet regulatory standards

and requirements

ROW shall be regularly cleared and

adequately maintained to ensure easy

access for inspection and maintenance.

Routine inspection of wellheads and

other facility shall be maintained to

ensure facility integrity.

Host communities shall be educated on

the expected spill response actions as

well as the necessity for prevention of

spill in the area.

Health risks and

hazards

SPDC shall treat all generated waste to

acceptable regulatory limit before

disposal to ensure that such waste do

not pose health risk.

HSE training and job hazard analysis

shall be conducted to ensure that staff

health and safety are not compromised.

Deployment of

workers for

various phases

of project

Possible conflict

with local

cultures

SPDC shall ensure that all staff

deployed to the area are briefed on local

cultures and taboos.

Movement/ other restrictions shall be

strictly enforced, e.g. fishing.

Possible

introduction and

spread of

diseases

especially STDs

SPDC shall maintain regular medical

examinations for all staff.

Abstinence/safe sex shall be encouraged

Abandonment Demobilization

and abandonment

Availability of

land for

alternatives use

Beneficial impact requires no

mitigation.

Hazards from

abandoned

facilities

Facilities such as wellheads that cannot

be removed from site shall be clearly

marked as ‘danger zone’ to warn

people.

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Disturbance/inte

rference









relationship




Alteration of

established

landscape

facilities.

SPDC shall develop or enforce detailed

abandonment programme, which shall

address the use and management of the

land after decommissioning and

abandonment.

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CHAPTER EIGHT

8.0 ENVIRONMENTAL MANGEMENT AND COMMUNITY DEVELOPMENT

PLANS

8.1 General

This chapter presents the Environmental Management and Community Development Plans

developed for all phases of the BCA FDP Phase 2 project to provide the guidelines

and procedures for managing the significant impacts of the proposed BCA FDP

project. This Plan shall be used to ensure that potential adverse impacts of the

BCA FDP project are reduced to As Low As Reasonably Practicable (ALARP)

while the significant positive impacts are enhanced to ensure sustainable

community development.

8.2 EMP Objectives

The overall objective of the Environmental Management and Community

Development Plans for the BCA FDP phase 2 project is to demonstrate that the

environmental aspects and the potential and associated impacts of the proposed

project have been identified, evaluated and measures put in place for mitigating

the significant adverse impacts in-line with Nigeria Environmental Policy,

SPDC HSE policy and ISO 14000 EMS Specifications as well as demonstrate

that SPDC has an effective plan for controlling the significant adverse impacts

of the proposed project.

This overall objective shall be achieved by:

♦ Ensuring compliance with stipulated legislation on protection of the

environment;

♦ Integrating environmental issues fully into the project development and

operational philosophies;

♦ Promoting environmental management awareness among workers;

♦ Rationalizing and streamlining existing environmental activities to add value

to efficiency and effectiveness;

♦ Providing standards for overall planning, operation, audit and review, and

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♦ Ensuring that only environmentally sound procedures are employed during the

project planning and execution.

♦ Presenting effective monitoring plan including parameters to be monitored,

frequency of monitoring and responsibilities for the impact indicators of the

project

In order to achieve the above objectives, the following issues are addressed in this

Environmental Management and Community Development Plan:

Environmental monitoring, and

Environmental audit,

8.3 Environmental Monitoring Programmes

SPDC shall comply with the DPR/FMENV regulatory requirements by establishing an

environmental monitoring programme for the BCA FDP phase 2 project. The

environmental components and corresponding impact indicators and frequencies to be

monitored are as presented in Table 8.1 while Table 8.2 presents the monitoring

programmes including the responsibility for the drilling discharge during the BCA

FDP.

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Table 8.1: Monitoring Programme for Environmental Components.

PROJECT

PHASE

ENVIRONMENTAL

COMPONENTS

INDICATOR

PARAMETERS

FREQUENCY RESPONSIBILITY

Site

Preparation

and

Operational

Phases

Soil/Sediments PH, Salinity, heavy

metals, TPH, etc.

Monthly

Line Department

Air quality Sox, Nox, Cox,

benzene, particulate

etc.

Monthly

Line Department

Surface water quality PH, Nutrients

content, BOD,

Suspended solids,

hydrocarbon

content, volatile

organic compounds

(VOC), etc

Monthly

Line Department

(PCW – HSE)

Ecology Diversity and

Abundance of flora

and fauna,

endangered species

Monthly

Line Department

Social/Health

Components

Community

relations

scholarships/social

infrastructures,

sponsorship of

social activities e.g.

sports etc.

Youths restiveness

Morbidity pattern/

General health

status

Bi-annually

Line Department

(PCW – HSE)

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Table 8.2: Drilling discharge monitoring programme (DPR Requirement)

Discharge Type Parameter/ effluent

characteristics

Monitoring Frequency Responsibility

Drilling fluids Volume/discharge

Toxicity, 96-hour LC50

[for each mud type and

major additive

proposed for use]

Oil content for based

mud

Petroleum

hydrocarbons [aliphatic

and aromatic] for oil

based mud.

pH

Heavy metals, e.g.

copper, lead, mercury,

nickel, total iron,

vanadium, arsenic,

barium, and total

chromium.

Grain distribution

Specific gravity

Hourly

Once per mud system

Every 305m of well depth. Once at the end of the well [from the lowest

section but not in the pay zone].

Every 305m of well depth - do –

- do –

- do –

Line Department

Drilling cuttings Volume/discharge rate

pH

Oil and grease content

Heavy metals as listed

above

Daily during discharge and

measure

duration of

discharge.

Every 305m of well depth.

- do –

- do –

Line Department

Deck drainage Volume

Oil and grease content On a daily basis

Once per week

Line Department

Blow-out

prev

entio

n

fluid

Volume Estimate monthly Line Department

Work-over

fluid

s/was

te

Quantity/weight

pH

Oil and grease content

Estimate monthly

Once per week

- do -

Line Department

Produced

form

ation

wate

r

Quantity/weight

pH

Total hydrocarbon

content

Heavy metals

Estimate and report during

vessel/tank

clean out/de-

sludging

Line Department

Oily waste waters Volume, pH, oil grease

content, salinity, TDS Estimate and record daily Line Department

Sanitary sewage Discharge rate

Coliform bacteria Estimate and record daily

Once per week

Line Department

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8.4 Environmental Audit

Environmental audit will be conducted on a regular basis for all operations facilities throughout

the life span of the BCA FDP project. This audit process shall be used to check the

prediction in the EIA as well as assess the environmental performance during the

operation phase of the project development. This will demonstrate that environmental

protection and management procedures as specified in the EIA are implemented.

8.5 Waste Generation/Management

Waste streams that would be generated during the operation of the BCA FDP project

have been identified, characterized and management/ disposal options evaluated. The

Waste management plan is targeted primarily at waste minimisation, waste reuse and

recycling such as reuse and recycling of drilling mud. Waste disposal targets would be

set annually to meet SPDC waste management policy.

The FDP has also considered waste elimination by designing out unnecessary waste

generating modules and has incorporated waste reduction opportunities such as

drilling of slim holes, use of slim width dredging, clearing of slim Right of Ways

(ROWs) and cluster drilling. Minimisation of waste process water would be achieved

with the deployment of a roofed mobile concrete barge production facility with

completely closed drain system. Gas would be gathered for use, as there would be no

continuous gas flaring thereby minimizing gaseous waste. Processes already exist to

measure and record quantity of waste generated.

8.5.1 Waste Characterization/Categorization

Solid waste: Domestic refuse scrap metals, drums and other containers (metal and

plastic), drill cuttings, drilling mud.

Aqueous waste: sludges, condensate, glycol, oil leaks, sanitary waste and lubricants.

Gaseous waste: fumes from combustion engines, flared gas, refrigerants and other

fugitive emissions.

8.5.2 Drilling waste (Used drilling mud and cuttings)

The estimated volume of drilled cuttings from the 11 planned wells for the BCA FDP

phase II project is 68,502.7 cubic ft. (1,918.1 m3). SPDC shall undertake the

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containment of this waste in skips at the drilling site and transport them to Forcados

Terminal for treatment and disposal at a designated dumpsite. The treatment will be

carried out using a Thermal Desorption Unit (TDU), which is an optimum technology

for treating hydrocarbon-contaminated wastes.

The components of the TDU consist of the following:

Inlet feeder, conveyor and metering bin.

Primary kiln in which the contaminants are desorbed from the oil.

Secondary combustion chamber, where desorbed organic contaminants are

destroyed.

Venturi inlet scrubber for quenching, particulate removal and acid gas

neutralization;

Control Trailer operation center for electric instrumentation and process

monitoring.

Treatment of drilling waste

The first step in the treatment programme will be laboratory analysis of the

contaminant type and concentration to ensure suitability for the TDU thermal

treatment process and compliance with environmental requirements. After the

analysis the result will be interpreted and the contaminated materials homogenised

and blended while the oversized materials, i.e., large rocks and other debris will be

screened out after which the materials will be subjected to thermal treatment.

The low thermal desorption process is characterized by:

•Minimal oil residue on treated cuttings down to less than 0.5 %

•Recycling of retrieved oil (computerized controlled process)

•Recycling of treated soil

•Recycling of retrieved water

•Recovered oil is collected for reuse in formulation of drilling muds or as feedstock

in the boiler process.

•Recovered water is used to moisture the processed soil at the outlet “Mixer”.

•Recovered soil will contain less than 0.5% oil. In most cases oil residue on treated

cuttings is as low as 0.1%. Reused for construction, filling material depending on

possibilities at the location of processing.


EIA of Benisede Catchment Area FDP Phase 2 June, 2005 V

The treatment is split into the following stages:

Stage 1: The waste material will be fed into the TDU via the Inlet Feeder and it is then passed

along an inclined conveyor into the Metering Bin mounted on top of the Primary kiln.

Stage 2: In the primary kiln the material is heated to temperatures in excess of the respective

boiling points of the contaminants to volatilize the various hydrocarbons fractions and remove any

moisture. The temperature is between 400 – 850oC depending on the contaminant and soil type.

Stage 3: The treated material will be discharged from the kiln into the Discharged Auger system

and then into an enclosed pugmill where water is sprayed into it for cooling and re-hydration. The

clean and re-hydrated drill cuttings passes through an air seal into a treated soil bin and then

placed in a containment area and tested to confirm that the clean up criteria has been met.

Stage 4: The secondary combustion chamber is designed for complete combustion of

hydrocarbons in the flue gases from the primary kiln.

Stage 5: The gases from the secondary combustion will be passed through the venturi scrubber for

cooling, separation and neutralisation of the gas before it is discharged from the Emissions Stack.

After testing the solid residual matter to confirm that it meets the applicable clean-up criteria. It

will then be transported off-site for beneficial end uses, such as industrial backfill, road sub-grade.

Etc.

Produced water

Wastewater shall of necessity be generated at various stages of the drilling project, and procedures

have been laid out to ensure a thorough treatment and disposal of all produced water to meet with

DPR and FMENV standards.

Treatment of produced water

Produced water from various sources shall be routed through the designated water treatment

system as follows:


EIA of Benisede Catchment Area FDP Phase 2 June, 2005 VI

Table 8.3 Produced water treatment systems.

Source

Treatment system

Produced water from production

separator

Production Hydrocyclone

Produced water from test separator Test Hydrocyclone

Produced water from skimmer L.P. Production Separator

Produced water from process gas

scrubbers.

Oil Treater and Degassing Drum

The hydrocyclone provides primary separation of the oil from the produced water streams. Water

discharged from the hydrocyclones will be routed to the degassing vessel, which operates at

atmospheric pressure. This vessel serves to degas the produced water stream and to provide

secondary separation of the oil from the water. When the produced water leaves the degassing

vessel after final processing, it will then be routed to the port slop tank.

Produced Water Disposal

The water from the process plant together with any free water in the cargo tanks will be put into

the port slop tank for settling. Once the sullage in the tank reaches the level of the decanting line

(3m), water from the bottom of the tank will be decanted overboard via the Oil Discharge

Monitoring Equipment (ODME).

Gaseous Emissions

Gaseous emissions result primarily from the burning of diesel as fuel for power units and gas

flaring. Although the resulting ambient pollutants concentration are not expected to impact

sensitive receptor.

SPDC shall however, run and maintain all power plants under optimal fuel efficient

conditions and where possible associated gas shall be used as fuel.

Oil and gas exploration and production activities, process equipment with controls shall be

designed and operated to minimise atmospheric emissions as it is currently practised.

Where possible flare gas would be used as fuel.

Aqueous Waste


EIA of Benisede Catchment Area FDP Phase 2 June, 2005 VII

These materials shall first be segregated, treated and disposed of in accordance with SPDC waste

management manual and regulatory standards.

In order to achieve a sound environmental management system the following issues are being

considered:

Improved planning and good housekeeping practices to minimise surplus and

contaminated chemicals.

Substitution with longer life products and those with lower impacts.

Recovery of useful components of some wastes including lead acid and wet

nickel/cadmium batteries. Alternatively, the heavy metals components (the hazardous

components) of the batteries shall be powdered and immobilised in cement blocks and

slabs and used for construction/building.

Solid waste

Solid wastes shall be cleared, properly packaged and disposed off at designated points. SPDC

shall also seek opportunity for waste minimisation through the use of the “reduce, reuse and

recycle / recover” philosophy.

Soild waste shall be sorted out into biodegradables and non-biodegradables. The biodegrables

shall be landfilled at designated point while the non-biodegradables shall either be re-used or

incinerated.

Environmental impacts arise from both the presence and volume of residues. In order to reduce

these residual effects, SPDC has taken into consideration:

Bulk transport and storage for high volume consumption items.

Refill and reuse of containers. Where possible, non-refillable containers could be returned to the vendor for reuse or to a company specialising in container refurbishment.

Sanitary/Sewage discharges

These include all sanitary waste and grey water that is from sinks, showers, garbage disposals etc.

It is generally assumed that one person produces 0.1m3

per day of sewage effluent (including

flushing). Therefore, the estimated volume of sanitary waste for 100 persons is 350m3/month.

This effluent is mostly water with traces of edible oils and soaps. With this knowledge, SPDC


EIA of Benisede Catchment Area FDP Phase 2 June, 2005

VIII

shall use the extended oxidation activated sludge type sanitary treatment unit. This unit is

designed to treat the sanitary sewage from the flowstation living quarters, which will

accommodate about 100 persons at the project construction phase.

All produced sewage will be routed to a receiving tank, which is equipped with macerator that

pulverises all the sewage. Seawater will be used as flushing medium for toilets.

Description of sewage treatment process

The extended oxidation activated sludge-type sanitary treatment unit consists of the following

main parts through which the sewage goes before it is eventually discharged into the sea.

1) An interceptor tank located upstream of the biological treating section, equipped with

macerator.

2) An aeration (oxidation) chamber with air diffusion system, where the material being

treated will be continuously and skangly aerated by means of insufflated air and mixed

with activated sludges.

3) A settling chamber where activated sludge will be separated and in part recycled to the

aeration chamber, while the treated water will flow to the chlorination chamber.

4) A chlorination chamber where the treated water will be disinfected by hypochloride. The

sewage will then be transported after chlorination to the government designated disposal

area.

5) A hypochloride closing system.

6) An air blower suitably designed to meet the air requirement of the treatment unit. It is

driven by an electric motor.

In a situation where the blower is out of use for any reason, air supply to the treatment unit

shall be provided by a connection to the platform compressed air distribution network.

8.6 Summary of waste management

8.6.1 Produced Water: Crude Oil along with associated produced water from the proposed BCA FDP

would be transferred to the (Forcados) Terminal for effective oil-in-water separation using the

Terminal treatment facility. Disposal of separated produced water would be disposed at

designated dumpsites (Kokori), which is an acceptable and compatible (no discernable effect)

recipient environment. The discharge of produced water at the Terminal meets and surpasses

current regulatory limits. However monitoring of produced water for harmful components and


EIA of Benisede Catchment Area FDP Phase 2 June, 2005 IX

quantification of produced water discharged are currently being conducted and shall continue to

ensure regulatory compliance for the BCA FDP project.

8.6.2 Pseudo-oil-based Muds and Cuttings: In line with company (SPDC) policy on oil-based muds,

only water-based or Synthetic (pseudo) oil-based muds have been identified for use under BCA

FDP project. No discharge of either mud or cuttings would be made to the environment, these

would shipped to Forcados Terminal for thermal desorption treatment using the thermal

desorption unit (TDU) plant. After which they will be discharged at designated sites or if there

exist an approved cuttings re-injection well they might be disposed in such a well. Volume of the

cuttings generated would be recorded.

8.6.3 Oil Spills: New techniques and technologies to prevent and minimise the risk of oil spills have

been incorporated into the BCA FDP. All flowlines would be constructed to standard sizing and

rating. Flowlines shall also be protected against corrosion using deep well cathodic protection

device. Flowline and equipment inspections/maintenance strategies necessary to ensure that oil

spills are minimised have been identified and would be deployed under this FDP. Implementation

of CAO SCADA for remote well monitoring would ensure quick leak detection. The mobile

concrete barge flowstation would be equipped with adequate spill response equipment for

containment purposes. Emergency procedures and the oil spill response tool developed under the

Environmental Sensitivity Index mapping project would be deployed in the event of an oil spill.

Processes and procedures are already in place to regularly conduct drills to test oil spill

contingencies and to record, report and investigate all oil spills. Results of investigations would be

fed back to identify actions to minimise the chance of recurrence and to continuously improve

performance. Annual targets would be set for reducing the volume of oil spilled and the number of

incidents.

8.6.4 Gaseous Emissions CO2, CH4, SOx, NOx, H2S, VOCs (including BTEX): Pollution prevention

and reduction have been fully considered in facility and process design in the BCA FDP. The

facilities have been designed for gas gathering for export purposes and utilization on site for

energy generation. The only source of emissions would be from operational flaring, as routine gas

flaring would be eliminated. Volume of operational gas flared would be recorded in order to

estimate quantities of gas components in view of greenhouse effect. Operational control would

ensure quantities of gaseous components are within regulatory limits and set targets. Emissions

are measured and targets set for continuous improvement. Noise reduction from source would be


EIA of Benisede Catchment Area FDP Phase 2 June, 2005 X

achieved through the use of electric drive pumps and soundproof generators. All relief systems are

designed to be piped to the flare to eliminate venting. Gaseous emissions monitoring would be

carried out regularly and values checked against regulatory limits.

8.6.5 Halons and CFCs: Absence of both Halons and CFCs shall be ensured within Benisede field

operations and in line with company policy that no Halon or CFC-containing equipment would be

deployed under this FDP. The zero stock of both Halon and CFCs shall be maintained by

specifying equipment with ozone-friendly alternatives and checking to ensure that all equipments

are compliant. Target set is to maintain current zero inventories.

8.7 Staff Resourcing and Training

It is planned to resource staff for the BCA FDP project through the current organisation including

other Area Teams and the company sponsored training program (Shell Intensive Training

Programme). Training shall be accomplished for current staff by liasing with South Forcados AGG

program for all new equipment particularly those related to gas lift and gas gathering. Efforts will

be made to train the station attendants to a minimum basic operation level to be able to provide

minimum intervention in operations if required.

8.8 Community Development Plan

As a strategy to create an enabling environment for our operations and to have a sustainable

License To Operate (LTO), three community Liaison Officers (CLOs) are assigned to Benisede

and its satellite fields (BCA FDP project area) to interface with the host and pipeline communities.

The CLOs carry out regular proactive visits, organize people parliament, Community Consultative

forum and Open Fora to enlighten the people on Shell roles and responsibilities. During such

engagements, the community expresses freely and openly their concerns, queries and grievances

for possible resolution.

For more effective communication with the communities and to enhance company community

relations, arrangements have been concluded to centrally position a CLO’s office at Ojobo and

another one at Peretorugbene community. The CLOs are require to spend at least two days each per

week in the field with a view to attending to and prompt resolution of community issues that may

arise. Beside, flowstation maintenance, pipeline surveillance, wellhead and flow line surveillance

contracts, etc are awarded to SPDC registered community contractors. These contractors are

encouraged to employ people from the locality so as to reduce youth unemployment and


EIA of Benisede Catchment Area FDP Phase 2 June, 2005 XI

restiveness. Efforts are constantly made to identify all outstanding key issues in the area, with a

view to resolving them.

Table 8.3: Shows a Stakeholder register template that will be maintained as recommended by the

VAR team. This replaces the community issues tracking register that has been in use for all SSA

communities.

Table 8.3: Stakeholder Register Stakeholder:

Benisede FDP

CLO:

Stakeholder

Contact:

Interface

Objectives

BENISEDE FDP CATCHMENT AREA COMMUNITIES

PCW-CLO

COMMUNITIES HRH, CDC AND INDIVIDUALS

Community engagement to build/strengthen relationship with host communities thereby

creating an enabling environment to work

S/N Key

project

activity/In

cident/Co

mpliant

Issues

arising

Required

Action

Date

Action

Assigned

Priority

(L/M/H)

Action

Party

Action

Due

Date

Status

(New/Ongo

ing/Hold/O

ver

due/Closed

Last

Review

Date

Next

Planned

Review

Review

Comments

Engagement with Government

Close contract is maintained with Governments of Bayelsa and Delta State respectively. Local

Government authorities are normally informed of SPDC activities in the area prior to

commencement, while key community issue/conflicts are discussed and resolved at the state level

with the Hon. Commissioner for environment, Bayelsa State and special adviser to the State

Governor on Mineral Resources, Delta State.

Community Assistant and Development plan

The BCA FDP communities have all benefited from the company’s CA/CD programme. A good

number of social infrastructural facilities were provided to the communities such as: Post primary

school and University scholarship to deserving students annually. In anticipating of the proposed

Field development projects, the Southern Swamp AGG, Pipeline and Flowline construction works,

etc., SPDC in 2001 signed a 5-year development plan Memorandum Of Understanding (MOD)

with Ojobo and peretorugbene communities, respectively. In the signed MOUs is a plan for inter-

dependency electricity project for the two communities.

Similar MOUs are developed for the Amabulou Federated communities. There is also a

development plan already put in place, as well as annual CD plan for some of the pipeline and

gateway communities. Detailed summary of CA/CD projects completed in the area, as well as the

current plan are shown in Tables 8.4 and 8.5.


EIA of Benisede Catchment Area FDP Phase 2 June, 2005 XII



XIII

Table 8.4: Completed and On-going CA/CD projects

Community

S/No

.

Project Year

Commenced/

Completed

Remarks/ Status

Ojobo 1.

2.

3.

4.

5.

6.

7.

8.

9.

10.

11.

12.

13.

14.

Furniture (Gbesa Gram. School)

Jss equipment

Potable water (borehole)

Potable water (distribution)

Renovation of cl. room. Blk/hall

Blk. of 6 cl. Rm. (Aya-Ojobo Primary School)

Class rm. blk/furniture (remedial work)

School Furniture

Water Hand Pump/ Water Up-Grade

Sandfill

Health centre

Micro-Credit

Training of Village Health Workers (VHWs) /

Traditional Birth Attendants (TBAs).

Electrification Extension

1986

1988

1989

1990

1992

1994

1995

1996

1999 (CD)

2000

1999

2000 (CD)

2000 (CD)

2001 (CD)

Functional

Functional

Non functional

Non functional

Functional

Functional

Functional

Non functional

Functional

Completed. Awaiting

equipment supply

Functional

Functional

Functional

Promised

Peretorugbene 1

2

3

4

Blk of 3 classblk

Staff Quarters

Science Block

Blk of 6 class room

-

-

-

2000 (CD)

Functional

Functional

Non Functional

( Needs renovation)

On-going

Tamogbene 1

2

3

4

5

6

Science Block

Market Stall

Blk of 6 class room

Cottage hospital

Radio house

Water

-

-

-

-

2000 (CD)

Functional

Functional

Functional

Awaiting commissioning

( Needs renovation)

Non Functional

On-going



XIV

Community

S/No

.

Project Year

Commenced/

Completed

Remarks/ Status

Amabulou

1

2

3

4

5

4 out board engines/boats

Water

Market stalls

Blk of 6 class room

Town hall

Guest house

2000 (CD)

2001 (CD)

-

-

-

Functional

On-going

Functional

Non Functional

( Needs renovation)

Functional

Norgbene 1

2

3

4

5

Water Rehabilitation

Water

Market stalls

Blk of 6 classblk

12 Rooms Guest House

2000 (CD)

-

-

-

-

On-going

Non Functional

Functional

Functional

Functional

Foutorugbene 1

2

Micro-Credit

Civic Centre

2001

1998

Functional

Functional

Oweigbene 1.

2.

3.

4.

5.

6.

Blk. of 6 cl. rm/furniture

Civic centre

Cassava mill

Gin distillery

Health Centre

Micro-Credit

1997

1998

1999

1999

1999 (CD)

2000 (CD)

Functional

On going

On going

On going

On going

Functional

Angalaweigbene 1

2

3.

4.

5.

Furniture

Block of 6 class room

Block of 6 class room

Micro-Credit

Health Centre

1988

1996

1998

2000 (CD)

2002

Functional

Functional

Functional

Assessment yet to be carried

out due to community crisis.

In 2002 plan

Obrigbene 1

2

3

Block of 6 Class room

Market Stalls

Civic Center

1993

1997

2000 (CD)

Functional

Functional

Ongoing

Ndoro 1.

2.

3.

Block of 6 class room/furniture

Potable water

Cassava mill

1996

1997

1999

Functional

Non functional

On going

Table 8.5: Current CA/CD projects plan -Summary

HOST 2001 2002 (Proposed 2003 2004 2005 2006 2007


EIA of Benisede Catchment Area FDP Phase 2 June, 2005 XV

COMMUNITY (Proposed

budget)

budget)

Ojobo Landscaping (N7.0m)

Electricity distribution

(N9.0m) Drainage (N7.0m)

Guest House (N8.0)

Ongoing Health centre

(N1.0m)

Renovation

of two six

class room

block

Water

scheme

Renovation

of

Community

Town hall

Electricity

Gas

turbine

Peretorugbene Landscaping (N7.0), Science

block renovation (N5.0)

Electricity distribution (N7.0m)

Health centre (N7.0), Micro-

credit scheme (N4.0m) and Sand

filling (N7.0)

Lawn

tennis court

Guest

house

Electricity

(Gas

turbine)

Concrete

pavement

road

Tamogbene Landscaping and sand filling

(N14.0), Ongoing Water project

(N4.0)

Micro-credit scheme (N5.0m)

Skills

Developme

nt

Civic

centre

Teachers

quarters

Renovation of six class

room block

Norgbene Landscaping and sand filling


(N2.0) Biz. . Dev./Micro-credit

scheme (N8.0)

Skills

Developme

nt

Civic

centre

Teachers

quarters

Concrete jetty

Amabulou Landscaping and sand filling


(N6.0) Micro-credit scheme (N5.0m)

SKILLS

DEVELOP

MENT

Cottage

hospital

Canalisation Electricity

PIPELINE

COMMUNITY

2001 2002 2003 2004 2005 2006 2007

Ekeremor

Torugbene Six class

room block

(N7.2m)

Foutorugbene Micro-credit

(N4.0m)

Health

centre

(N7.0)

Oweigbene Civic centre (), Cassava mill

(N54,000), Gin distillery

(N335,000), Micro-credit

(N0.6m) and Health centre

(N20m)

Obrigbene Civic centre (N0.69m)

Angalaweigbene Renovation of six class

room block (N5.0)

8.9 Decommissioning and Abandonment Plan

The overall objective of the decommissioning/abandonment plan is to demonstrate that effective

programme exist to restore the site to its original status much as possible.



XVI

On reaching the end of the project life span, a decommissioning team shall be set up to plan and

implement the guidelines for decommissioning/abandonment to ensure that the best and

practicable methods available are employed to clean up the project site.

Wells will be properly abandoned as per SPDC abandonment procedure of setting adequate

cement plugs and a bridge plug prior to installing a blind flange on the wellhead. See Fig. 8.3.

Figure 8.3: SPDC well abandonment Procedure



XVII

CHAPTER NINE

9.0 CONCLUSION

This Environmental Impact Assessment (EIA) report was prepared adopting a multi-

disciplinary team approach consistent with the FEPA (now FMENV) Sectoral Guidelines

for Oil and Gas Projects and the DPR’s Environmental Guidelines and Standards for

Petroleum Industries in Nigeria (EGASPIN, 2002). The EIA study involved detailed

literature search, field observation and in situ measurements, field sampling, laboratory

analyses/data analyses, impact identification/evaluation, and reporting.

The BCA FDP phase 2 project is designed to ensure maximum recovery of the huge

hydrocarbon deposits within the Benisede, Akono and Opomoyo fields and also test

neighbouring reserves. This will, in addition to increasing the national hydrocarbon

reserves, increase the national foreign earnings as well as boost SPDC crude oil

production target. The BCA FDP project will also create employment opportunities and

consequently increase the standard of living of some Nigerians.

However, the EIA report has highlighted the potential and associated adverse impacts on

the environment. These impacts are mainly short-term, residual, highly localized and

reversible on the immediate environment.

Mitigation/Amelioration measures have been proffered for each of the identified potential

and associated adverse impacts of the BCA FDP project. Also, an Environmental

Management Plan (EMP) has been developed to ensure that the identified potential

impacts can be reduced to “as low as practically reasonably” (ALARP). Most importantly,

monitoring programmes and environmental auditing of the BCA FDP project have been

recommended throughout the life cycle of the project to ensure that all impact indicators

for all the environmental components at every phase of the project are within statutory

limits.



XVIII

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petroleum related pollution in Nigeria. Research Planning Institute, Inc. Columbia, South

Caolina, USA.

SAGE Engineering AG for Mobil Producing Nigeria Unlimited’s Omon/Usari, Oct 1994.

Sokal, R.R. and Rohlf, F. J. (1995). Biometry. Colt Freeman and Company, New York. 887pp.

The Mineral Oil Safety Regulations: 1969 Petroleum Act, revised 1995.

Tobor, J. G. (1991). The fishing industry in Nigeria. Status and potential for self sufficiency

in fish production. NIOMR tech. Paper No. 54. NIOMR Lagos 33pp.

UNEP. (1985). The impact of Water based Drilling Mud discharges on the Environment. Industry and

Environment Overviews Series.

Van Wambeke, A. R. 1962. Criteria for classifying tropical soils by age. J. Soil Sci. 13:124 – 132.

Wahden, A. A., M. M. El-Bahal and A. A. Moustafa. 1984. Drainage effect on root distribution systems.

Egypt. J. Soil Sci. 24: 201 – 208.



XXIII

Wathern, P. (1986). Environmental Impact Assessment (Theory and Practice). John Wiley & Sons Ltd. Pp 17-

97.

Whiteman, A. 1982. Nigeria: its petroleum geology, resources and potential. 2 volumes. Graham and

Trotman, 394pp.

Zar, J. H. (1984). Biostatistical Analysis 2nd

edition. Prentice Hall, London.



XXIV

APPENDIX II

METHODOLOGIES FOR BASELINE DATA ACQUISITION

Methodologies for baseline Data Acquisition

The details of the methodologies adopted for environmental baseline data acquisition for each of the

environmental components and the Impact indicators are described below.

Relief, Topography and Hydrology

The field is mainly a fresh water swamp environment and the topographical features of the study

area are streams, creeks, roads and buildings. A systematic sampling technique was adopted as a

scheme to extrapolate data evenly about the target area for the study. Outboard Engine Boat and foot

were used to traverse the entire field. The distribution and pattern of the physical features

characterizing the terrain within the field were used as common approach to landscape description

and assessment.

Climate and Meteorology

Eight temporal Climatic and Meteorological station for acquisition of data were established at

designated areas within the field and also historical data from Warri weather station. The baseline

data from activities at the Flowstation, host communities, Wellheads and slots were collected.

The ambient air temperature, relative humidity, rainfall, wind speed and direction (taken at a height

of 1.5m above ground), cloud cover and prevalent insolation were the meteorological parameters

determined during the fieldwork period. The data obtained are being compared with existing

historical data for Warri, the nearest synoptic stations.

Air Quality

The Air Quality/Noise stations are the same sites used for meteorological data acquisition. Digital air

quality equipment were used to determine the concentrations of NH3, SO2, CO, CO2 and NOx, VOC

and TSP in the air. At each sampling station readings were taken continuously for 15 minutes and

extrapolated to an hourly reading for three hours per sampling site taken as three replicate readings.

TABLE 1.0:ENVIRONMENTAL COMPONENTS AND IMPACTS INDICATORS

S/NO ENVIRONMENTAL COMPONENTS ENVIRONMENTAL IMPACT INDICATORS



XXV

1.

2.

3.

4.

5.

6.

7.

8.

9.

10.

11.

12.

Relief / Topography & Hydrology

Air Quality, Climate and Meteorology

Water Quality (Surface Water)

FISHERIES / HYDROBIOLOGY/

SEDIMENT,

Geology / Hydrogeology

Soil, Agriculture & Land Use

Vegetation / Forestry

Wildlife

Noise / Vibration / Radiation

Health Risk Assessment

Community / Socio-Economic Impact

Assessment

Waste Management

Drainage / Discharge, Hydrologic balance,

sedimentation, erosion, topography.

SPM, NOx, SOx, CO2, CO, VOC, etc., Wind speed &

direction, Relative humidity, Rainfall, cloud, etc

Total solids (Dissolved solids, suspended solids);

turbidity, other physico-chemical and microbiological

characteristics, Aquatic toxicity tests, seabed sediment,

physico-chemical / microbiological characteristics.

Diversity, Abundance, productivity, catch/yield of

fishes. Fish tissue analysis. Qualitative and quantitative

information on benthos.

Borehole drilling for Stratigraphical / Lithologic

characteristics, ground water level, direction and quality

(Physicochemical and microbiological characteristics).

Soil type and structure, physico-chemical and

microbiological characteristic land use types;

recreational, industrial, agricultural, residential,

institutional and commercial. Species checklist,

characterization of plant pollution, taxonomy, diversity

and productivity load, locations and characteristics.

Identification of types and economic importance of trees

in the study area.

Identification of wildlife types, parks, estimate

population, behavioral pattern and habitat requirement;

endangered species and ecological interactions.

Ambient noise level, exposure limits of impulsive and

persistent noise generated in the environment, the

proximity of noise sources to human and ecological

habitants; day and night disturbance, hearing loss

communication interference.



XXVI

Health risks, public health and medical services, water

supply and demand, analysis of medical records.

Needs and concern of host communities, Data on

settlement, man-made features, socio-economic /

historical rites, population, income, recreational

facilities, social organizations and institutions,

occupation and employment structure, culture, heritage,

etc.

Waste streams, handling, treatment and disposal, etc.

Noise and Vibration

Noise levels at various distances from point sources were measured using a decibel noise meter.

Measurements were taken for 15 minutes at each point. The range of the noise level was noted and

the true mean computed.

Vegetation/Forestry Studies

Vegetation studies were carried out to determine the baseline status of the field vis-à-vis the species

composition, diversity, and population of plant species as well as their health status (plant

pathology). The density and percentage of the key tree species and the herbaceous layer were

determined while rare and endangered plant species and all those of special significance to the

ecosystem and the local economy were categorized (Oosting, 1956). The species diversity of the

plants were calculated as the ratio between the number of species and “importance value” which, for

the purpose of this study, were taken as the number of individuals per quadrant (Odum, 1971). Both

general and specific characteristics of the vegetation were assessed by determining their floristic

composition, life form and biological spectra.

The vegetation studies were carried out along the slots, within the wellheads and at the sampling

stations for soil studies. Random quadrant sampling technique was also employed in the field.

At each sampling location, two quadrants measuring 10m x 10m and 1m x 1m were used to study

trees and shrubs, and herbs respectively. The plant community structure was observed and the plant

species within each quadrant were identified. The floral and vegetative parts of unidentified plant

species were collected, pressed in the field with herbarium press, and taken to the laboratory for



XXVII

herbarium studies and identification. The population of the dominant plant species in each quadrant

was determined by counting.

The life form spectra of the various plant communities within each of the sampling locations was

analysed using the Raunkerian life form classification scheme (Raunkiaer 1934) which divides the life

form into the following:

PHANEROPHYTES (Woody Plants)

- Megaphanerophytes (Mgp) - Trees over 30m high

- Mesophanerophytes (Mep) - Trees from 8 - 30m high

- Microphanerophytes (Mip) - Trees and shrubs 2 - 8m high

- Nanophanerophytes (Nanop) - Shrubs under 2m high

EPIPHYTES (Epi) - Air plants with no roots in the soil.

CHAMAEPHYTES (Cha) - Plants with surviving buds close to the ground surface. In this

study, climbers were included in this class.

HEMICRYTOPHYTES (Her) - Plants with surviving buds at the ground level.

CRYPTOPHYTES (Cry) - Plants with surviving buds below the ground level. This includes

rhizomes, corms, tubers and geophytes.

THEROPHYTES (The) - These are annual plants. Mature leaves of the commonest plants

were collected for plant tissue analyses.

Pathological investigations were carried out by moving across each of the various micro ecotypes and

farms within and around the sampling locations. This was aimed at determining, as well as listing the

pests and diseases of crops. Disease severity for each crop was determined by the use of standard

disease severity index expressed as infection indices.

Table 1.1: Infection indices for different levels of disease severity

Infection Index Description

0

1

2

No infection

Very light infection

Moderate infection



XXVIII

3

4

Severe infection

Very severe infection

Diseased plant/crop parts were aseptically collected using a sharp knife into sterilized polythene bags

for further pathological studies in the laboratory.

Photographs were taken of the key vegetation types and other features of interest.

Soil and Sediment Studies

Twenty-five soil sample stations were established within the field at two-depth points 0-15 and 15-

30cm. The sampling points were initially pre-determined during using maps and other materials

provided by the asset holders. However, during the field study, the exact positions of the sampling

points were slightly modified at some sites as a result of factors such as accessibility, nature of

terrain, the ability of the Global Positioning System (GPS) to receive signals and safety

considerations.

The soil samples were collected at different landuse types and geomorphology. At each point,

composite sample were collected at two depths (0-15 and 15-30cm) using a stainless steel auger. The

samples were placed in polythene bags and labelled accordingly using the acronyms “SS” for soil

sample.

At each sampling point, soil samples were collected from six different points and composited for

each of the depths specified above. Hand metal soil auger was used for the sampling. The samples

were collected into appropriately labeled polythene bags in accordance with the quality assurance

criteria as contained in the environmental guidelines and standards for the petroleum industry in

Nigeria (EGASPIN, 2002). The samples were air-dried in a dust free environment, sieved with 2mm

sieve and were used for physico-chemical analysis.

Agriculture and Land use

The land use of the field includes:

Settlement/roads

Farming

This Land use patterns evolve as a result of:

Changing economic consideration inherent in the concept of the highest and best use of

land,



XXIX

Imposing legal restrictions on the use of land, and

Changes in existing legal restrictions.

Hydrogeology/ Geophysical Investigation

Borehole/groundwater samples were collected from four existing and six new boreholes. The

modified Hach groundwater sampler was used to collect samples after flushing the holes. In situ

measurements for pH, temperature, conductivity, salinity, TDS and Turbidity were conducted for

these samples. One core sample was collected from each drilled borehole.

Commercially available resistivity meter (ABEM SAS 300 C Terrameter) in combination with its

booster (SAS 2000) were used for the routine field survey. VES measurements were carried out

using Schlumberger array principle with four (4) cycle readings. It entails continuous measurement

of earth electrical resistivity by the injection of electrical current via a pair of outwardly displaced

electrode (C1 and C2) and a measurement of the resulting potential drop across another pair of

inwardly displaced electrode (P1 and P2) all of which are planted in the same spread line. Increase in

depth of investigation was achieved by successive increase in C1, C2 separation with the P1, P2

separation kept fixed in principles, but only increased when readings become too low for accurate

determination.

The potential electrode was kept constant for successive measurement unlike changing the position

of the current electrode. The potential positions were changed when the voltage reading became too

small to be accommodated by the instrument’s sensitivity. However, for every measurement, a ratio

of potential electrode spread to current electrode was kept close to 1.5.

Resistance measurements at each electrode position were displayed on the Terrameter. This

information was read off and subsequently keyed on the ABEM Super-VES interpretation

programme for analysis. A quality check of this data was done by a curve matching to eliminate

noise recorded along with the near subsurface information.

The commercial software (The Super-VES programme) used for the interpretation of the data,

presents graphical display of the subsurface representation, layer and possible aquifers.



XXX

To achieve significant results in the area, five (5) VES traverses VES-1, VES-2, VES-3, VES-4 and

VES 5 were run to cover the area. Due to field constraints, a maximum spread (AB/2) of 220m was

achieved.

Wildlife/Biodiversty

The wildlife study cuts across the entire field.

Methodology of sample collection include:

* Visual observation and documentation of their droppings

* Oral discussions with natives of the study area

* Tree beating, purpose mark, feathers, shells etc.

* Observation of bush meat in the local markets at Peretorugbene, Tamogbene and Ojobo.

Information on available species and relative abundance was obtained through oral interview and

discussion with artisanal hunters and indigenes.

The key parameter of study are the:

* Species composition/abundance

* Reproduction method

* Feeding method

* Wildlife habitat

Aquatic Studies

Thirty-five surface water stations and thirty-five sediment stations were sampled. For each sample

station, phytoplankton, zooplankton, benthos, microbiological, and physicochemical analyses were

carried out. Samples were collected from the Brass creek, slots and creeklets. In-situ measurements

were carried out in the field for pH, temperature, turbidity, salinity, TDS, DO, Conductivity.

Fish and Fisheries Study

Fishery study was carried out in Brass creek (the major water body) and creeklets within the field.

Methods used for fishery studies included:

* Direct Fishing

* Direct visual observation on site

* Collection of representative fish specimen from fishermen.

* Discussions with groups of fishermen and fishmongers in every community visited.



XXXI

Fish samples collected were preserved in well-labelled plastic containers containing ice chips.

Key Parameters Studied include the following:

* Morphometric measurement: Standard length, total length (condition factor)

* Pathological and parasitic infections

* Physical observation of operculum chambers, gills and gonads

* Fish composition and abundance study.

Waste Management Inventory of waste sources was taken at specific points in the Houseboat and the host communities.

Waste types include food wastes, paper wastes, oily rags and garden wastes.

Social Impact Assessment

Five host communities were consulted in this project. A field interaction was established between the

study team, SPDC project team and five host communities through interviews and meetings to elicit

and clarify view about the project. In this regard, a meeting was held on the 14 - 15th

of November

2002 with the host communities. The communities visited include Ojobo, Peretorugbene,

Torugbene, Owegbene and Amabolu.

Questionnaires were designed to cover biographical data, economic status, health status, and the

respondents’ attitudes to the project activities. A total of 25 questionnaires were randomly distributed

within each of the five communities. This number was considered as a representative sample for the

purpose of this exercise. For respondents that could not read or write, an interpreter was used to

facilitate the filling of such questionnaires.

In order to obtain further information on each of the communities and the commitment of the

Government and SPDC on infrastructural development, oral interviews were conducted with

community/opinions leaders.

Health Impact Assessment

The assessment of the health impacts was based on the baseline data gathered using the following

techniques:



XXXII

o Focus group discussions and community consultations

o Community health surveys through interviews and administration of questionnaires,

o On the spot observation and visual appraisal,

o Use of relevant health centre statistics, and

o Experience and professional judgment of the consultant.

Questionnaires were distributed to literate members of the host communities. Those who were not

literate were interviewed. In all, 25 questionnaires were filled and returned while 20 interviews were

conducted and recorded in each community.



XXXIII

SOCIAL IMPACT ASSESSMENT (SIA) QUESTIONNAIRE

FOR BENISEDE CATCHMENT AREA FDP

Community/Settlement:--------------------------------------------------------------------------

LGA:-------------------------------------------------------------------------------------------------

State:-------------------------------------------------------------------------------------------------

Section A: Respondent’s Socioeconomic Data

1. Sex

1.1. Male

1.2 Female

2. Age

2.1 10 – 19years

2.2 20 – 29years

2.3 30 – 39years

2.4 40 – 49years

2.5 50 – 59years

2.6 60 – 69years

2.7 70 and above

3. Marital Status

3.1 Single

3.2 Married

3.3 Divorced/ Separated

3.4 Widowed

4. Total size of household:………..

5. Age and Sex structure of household members

Age

(years)

Male Female Total

0 – 4

5 – 12

13 – 19

20 – 49

50 – 69

70 +

6. Status of Respondent

6.1 Traditional Ruler

6.2 Church Leader

6.3 Councilor

6.4 Family Head

6.5 Union Leader

6.6 Settler / Non – Native



XXXIV

6.7 Others (Specify)

7.0 How long have you lived in this settlement?

7.1 0 – 5years

7.2 6 – 10years

7.3 11 – 15years

7.4 16 – 20years

7.5 Above 20 years

7.6 Since birth

8. What is your religion?

8.1 Christianity

8.2 Islam

8.3 Traditionalist

8.4 Atheist

9. If you are a farmer, estimate the average size of your farmland in plots of land or acres / hectares.

9.1 Plot of land (Nos.)……………..

9.2 Acres / hectares………………..

10. How did you acquire the land?

10.1 Family inheritance

10.2 Rented / leased it

10.3 Bought it

10.4 Sharecropping

10.5 Others

11. What crops do you grow? (Name according to importance)

11.1:…………………………………………

11.2:…………………………………………

11.3:………………………………………...

11.4:………………………………………...

11.5:……………………………………….

12. In the past five years, what has been the nature of your harvest?

12.1 Increasing

12.2 Decreasing

12.3 The same

13. If decreasing, what do you think is responsible (record verbatim)

…………………………………………

…………………………………………

………………………………………..

……………………………………….

14. Level of Education



XXXV

14.1 Primary school

14.2 Secondary school

14.3 Vocational / Technical school

14.4 Tertiary school

14.5 No Formal Education

15. Occupation

15.1 Farming

15.2 Fishing

15.3 Technician / Artisan

15.4 Trading

15.5 Business / Contractor

15.6 Civil Servant

15.7 Retired

15.8 Student / Apprentice

15.9 Unemployed

15.10 Others (Specify):……….

16. Level of Weekly Income (Naira)

16.1 1,000 – 10,000

16.2 11,000 – 20,000

16.3 21,000 – 30,000

16.4 31,000 – 40,000

16.5 41,000 – 50,000

16.6 51,000 – 60,000

16.7 61,000 – 70,000

16.8 71,000 – 80,000

16.9 Above 80,000

17. If you also fish, what tools do you use?

17.1 Net (canoe)

17.2 Hook

17.3 Trap / basket

17.4 Any other (specify)……………

18. Where do you fish?

18.1 Rivers / Creeks

18.2 Ponds / lakes

18.3 Flooded areas

19. What has been the nature of your fish yield in the past five years?

19.1 Increasing

19.2 Decreasing

19.3 The same

20. If decreasing, what do you think is responsible? (Record verbatim)



XXXVI

20.1:………………………………………

20.2:………………………………………

20.3:……………………………………...

21. What is your weekly income from fishing ……………………….(naira)

SECTION B: SOCIAL IMPACTS

22. What period of the year is important to your community for:

22.1 Farming…………………..

22.2 Fishing……………………

22.3 Trading…………………..

22.4 Festivals…………………

23. What are the important environmental resources in your community

23.1 Forest resources

23.2 River / Creek water

23.3 Ancestral sites

23.4 Animals

23.5 Others (specify)……………..

24. Name the sacred sites in your community

24.1 ………………………….

24.2 ………………………….

24.3 ………………………….

24.4………………………….

25. List the environmental problems in the settlement

25.1 Soil fertility

25.2 Pest attack / invasion

25.3 Erosion problems

25.4 Flooding

25.5 Oil pollution / spillage

25.6 Others (specify)……………..

26. Has your economic activity (ies) been affected in any way in the past two to five years?

26.1 Yes

26.2 No

27. If yes, in what specific way have you been affected and what is responsible in your opinion?

27.1 ………………………………

27.2 ………………………………

27.3 ………………………………

28. Has your fishing ground/farmland been lost/reduced in size to company’s operational activities?

28.1 Yes



XXXVII

28.2 No

29. If yes, in what way(s) did you lose the fishing ground/farmland?

29.1 ……………………………….

29.2 ……………………………….

29.3 ………………………………..

Section C: Attitude towards Oil/other Companies

30. Name the companies within your settlement area

30.1 Shell Pet. Dev. Co.(SPDC)

30.2 Agip (NAOC)

30.3 Texaco

30.4 Chevron

30.5 Mobil

30.6 Others(specify)

31. What have you gained personally from the company(ies) operation in your area?

31.1 Employment

31.2 Scholarship for children/ward

31.3 Skills acquisition

31.4 None

32. If none, what personal benefit do you expect from the company(ies)?

32.1 Employment opportunities

32.2 Award of scholarships

32.3 Small monetary grant to farmers/fishermen

32.4 Provision of agricultural inputs/tools

32.5 Others(specify)………

33. What has your community gained from the oil/other companies in your area?

33.1 Provision of portable water

33.2 Electricity supply

33.3 Healthcare facility/center

33.4 Repair/tarring of community/link roads

33.5 Assistance with school building/chairs and tables

33.6 None


34. If none, what would you expect the company (ies) to do for your community?

34.1 Employment opportunities

34.2 Education / scholarship

34.3 Provision of portable water supplies

34.4 Electricity / road / market

34.5 Assistant with agricultural inputs

34.6 Others (specify)…………………..

35. What is your attitude towards oil / other companies who or wish to work in your area?

35.1 Support / welcome their activities

35.2 Resist their presence



XXXVIII

35.3 Demand compensation

35.4 I don’t care about them

36. What industry related social problem does to your community experience?

36.1 Youth delinquency

36.2 Land Dispute

36.3 Cheiftancy tussle

36.4 Inter family problems

36.5 Inter village tribal conflicts

36.6 Unemployment

36.7 Alcoholism / prostitution


37. Who should speak for the community on company – community matters?

37.1 Community Leader / Paramount Chief

37.2 Community Chief

37.3 The Youth Leader

37.4 Community Representatives

Thank you very much for the co – operation .



XXXIX

DETAILED NATIONAL AND INTERNATIONAL LEGISLATION AND CONVENTIONS ON

THE ENVIRONMENT

Ordinance of 31 December 1914: Minerals Oil Ordinance.

Ordinance of 1 January 1918: Ordinance Concerning the Regulation of Importation, Conveyancing and

Storage of Petroleum and Other Inflammable Oils and Liquids.

Ordinance of 1937: Forest Ordinance - Northern Region (as amended 1960)

Act No. 31 of 4 October 1956: Oil Pipelines Act.

Regulations of 1 June 1958: Mineral Oils (Safety) Regulations.

Ordinance of 1 June 1958: Ordinance Concerning the Regulation of Importation, Conveyancing and

Storage of Petroleum and Other Inflammable Oils and Liquids.

Act No. 37 of 16 August 1958: Factory Act.

Regulations of 11 April 1963: Mineral Oils (Safety) Regulations.

Act No. 9 of 1 January 1965: Oil Terminal Dues Act.

Act No. 17 of 11 June 1965: Hydrocarbon Oil Refineries Act.

Act No. 24 of 1965: Oil Pipelines Act(Amendment).

Act No. 1 of 1 January 1967: Explosives Act.

Regulations of 1 January 1967: Explosives Regulations.

Act No. 28 of 13 July 1967: Petroleum Control Act.

Regulations of 13 July 1967: Petroleum Control Regulations.

Act No. 34 of 22 April 1968: Oil In Navigable Waters Act.

Regulations of 22 April 1968: Oil in Navigable Waters Regulations.

Decree No. 51 of 14 November 1969: Petroleum Drilling and Production Decree.

Regulations of 27 November 1969: Petroleum (Drilling and Production) Regulations.

Act No. 31 of 10 June 1971: Sea Fisheries Act.

Act No. 38 of 26 August 1971: Territorial Waters (Amendment) Act.

Act of 24 October 1972: Nigerian Mining Corporation Act.

Regulations of 31 March 1973: Petroleum (Drilling and Production) (Amendment) Regulations.


EIA of Benisede Catchment Area FDP Phase 2 June, 2005 XL

Act No. 25 of 4 June 1973: Petroleum Technology Development Fund Act.

Decree No. 16 of 1 April 1973: Petroleum (Amendment) Decree.

Act No. 33 of 14 August 1973: Sokoto-Rima Basin Development Authority Act.

Decree No. 11 of 14 February 1974: Endangered Species (Control of International Traffic and Trade)

Decree.

Act No. 35 of 7 November 1975: Petroleum Production and Distribution (Anti-Sabotage) Act.

Act No. 25 of 15 June 1976: River Basins Development Authorities Act.

Decree No. 49 of 22 September 1976: Petroleum (Amendment) Decree.

Decree No. 37 of 3 May 1977: Petroleum (Amendment) Decree.

Act No. 33 of 1 April 1977: Nigerian National Petroleum Corporation Act.

Act No. 6 of 29 March 1978: Land Use Act.

Act No. 46 of 30 July 1979: Kanji Lake National Park Act.

Act No. 87 of 15 June 1979: River Basin Development Authorities Act.

Act No. 99 of 28 September 1979: Associated Gas Re-injection Act.

Act No. 20 of 31 December 1983: Special Tribunal (Miscellaneous Offences) Act.

Regulations of 1 January 1985: Associated Gas Re-injection (Continued Flaring of Gas) Regulations.

Act No. 25 of 1 April 1985: Endangered Species (Control of International Trade and Traffic) Act.

Act No. 35 of 1 October 1986: River Basins Development Authorities Act.

Regulations of 23 February 1988: Petroleum (Drilling and Production) (Amendment) Regulations.

Decree No. 11 of 3 March 1988: Arbitration and Conciliation Decree.

Decree No. 58 of 30 December 1988: Federal Environmental Protection Agency Decree.

Decree No. 42 of 25 November 1988: Harmful Wastes (Special Criminal Provisions etc.).

Regulations of 6 December 1989: Petroleum (Drilling and Production) (Amendment) Regulations.

Decree No. 50 of 29 December 1989: Natural Resources Conservation Council Decree.

Regulations of 15 August 1991: National Environmental Protection (Effluent Limitation) Regulations.

Regulations of 15 August 1991: National Environmental Protection (Pollution Abatement in Industries

and Facilities Producing Waste) Regulations.



XLI

Regulations of 15 August 1991: National Environmental Protection (Management of Solid Hazardous

Wastes) Regulations.

Decree No. 36 of 22 August 1991: Federal National Parks Decree.

Environmental Guidelines and Standards for the Petroleum Industry in Nigeria EGASPIN 2002.

Decree No. 23 of 9 July 1992: Decree Establishing the Objectives Etc. of the Oil Minerals Producing

Areas Development Commission.

Decree No. 59 of 2 August 1992: Federal Environmental Protection Agency (Amendment) Decree.

Decree No. 86 of 10 December 1992: National Environmental Protection (Management Procedure on

Environmental Impact Assessment) Regulations.

Decree No. 94 of 23 August 1993: Nigerian National Petroleum Corporation (Projects) Decree.

Decree No. 101 of 23 August 1993: Water Resources Decree.

Regulations of 1 April 1995: Petroleum (Drilling and Production)(Amendment) Regulations.

Environmental Impact assessment, Sectoral Guidelines 1995. Procedural guidelines.

Environmental Impact assessment, Sectoral Guidelines 1995. Oil and gas industry projects.

Regulations of 12 February 1996: Petroleum (Drilling and Production)(Amendment) Regulations.

Regulations of 12 February 1996: Petroleum Refining (Amendment) Regulations.

Decree No. 8 of 29 March 1996: Oil and Gas Free Export Zone Decree.

Decree No. 9199 of 23 March 1999: Decree Concerning Deep Offshore and Inland Basin Production

Sharing Contracts.

International Guidelines, Conventions and Agreements

In addition to the national laws/regulations, Nigeria recognises the World Bank Operational Directive

4.01 “Environmental Assessment”, of 1991, which classifies projects according to the nature and extent

of their environmental impacts and support the use of EIA as the key tool for achieving sustainable

development. Moreover, Nigeria is a party/signatory to a number of Environmental Treaties and

Conventions. A list of some international conventions and agreements to which Nigeria is signatory or

party is presented below.

International Environmental Conventions to which Nigeria is Signatory or Party



XLII

YEAR CONVENTION/AGREEMENT

1948 Convention of the Intergovernmental Maritime Consultative Organization

(IMCO)

1954 Convention for the Prevention of Pollution of the Sea by Oil (not the 1978

Protocol)

1958 Convention on fishing and conservation of living Resources of the High Seas

(note: into force 20 March 1966)

1958 Convention on the High Seas

1958 Convention on the Continental Shelf

1958 Convention on the Territorial Sea and Contiguous Zone

1968 African Convention on the Conservation of Nature and nature Resources

1969 Convention on Civil Liability for Oil Pollution Damage (not the 1976 and

1992 Protocols)

1972 Convention concerning the Protection of the World Cultural and Natural

Heritage

1972 Convention on the Prevention of Marine Pollution by Dumping of Wastes and

other Matter

1973 Convention to Regulate international trade in Endangered species of Fauna

and Flora (CITES)

1974 International Convention for the Safety of Life at Sea

1979 Convention on Conservation of Migratory species of Wild Animals

1981 Convention for Co-operation in the Protection and Development of the

Marine and Coastal Environment of the West and Central African Regions

1982 Convention for Co-operation in the Protection and Development of the

Marine and Coastal Environment of the West and Central African Regions

1985 Vienna Convention for the Protection of the Ozone Layer

1987 Montreal protocol on Substances that Deplete the Ozone Layer

1989 Basle Convention on the Control of Trans boundary movements of Hazardous

Wastes and their Disposal

1990 Convention on Oil Pollution Preparedness, response, and Co-operation

1992 United nations Framework Convention on Biological Diversity

1992 United Nations Framework Convention on Climate Change (+ 1997 Kyoto

Protocol)

SPDC


253

4.1: Ambient Air Quality Measurements

Parameters

Sample Point

AS1 AS2 AS3 AS4 AS5 AS6 AS7 AS8 AS9 AS10 DPR

LIMITS

CO

ppm

1.33 3.51 <0.01 2.23 0.76 1.06 1.11 <0.01 1.35 1.05 11.4-22.8

CO2

ppm

4.67 7.33 3.13 4.55 3.41 3.93 3.04 3.13 2.16 3.08 25.0

NO2

ppm

2.54 8.20 2.13 5.43 2.42 1.87 2.31 2.13 2.43 5.19 75-113

SO2

ppm

2.41 9.21 2.77 4.54 2.27 1.61 3.12 2.77 3.11 1.90 26-260

TSP

µg/m3

15.52 98.63 17.54 43.57 23.52 17.81 21.50 17.54 16.43 16.60 250-600

VOC

µg/m3

0.48 1.52 0.10 0.73 0.34 0.10 0.12 0.10 0.23 0.12 160

SPDC


44 of 253

Table 4.2:

Noise Level

and

Radiation

measureme

nts

Parameter

Sample Points

S R

Kw/m3

FR

Kw/m3

Noise (dB)

AS1 1.23 <0.01 67.50

AS2 1.21 2.22 93.50

AS3 <0.01 1.24 53.73

AS4 1.20 2.15 72.50

AS5 1.12 <0.01 56.51

AS6 1.34 <0.01 57.45

AS7 1.25 <0.01 52.52

AS8 <0.01 1.24 53.73

AS9 1.76 1.01 52.61

AS10 1.21 <0.001 53.20

DPR

LIMIT

6.310 6.310 80-100

SPDC Appendix


253

Table 4.3: Physico-Chemical Characteristics of Soil

Sample code

Parameters

SS 1

SS 2

SS 3

SS 4

SS 5

SS 6

SS 7

SS8

SS9

SS10

Depth 0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

Physico-chemical

PH 5.0 5.1 5.4 5.3 5.3 5.2 5.1 5.0 5.6 5.1 5.3 5.2 6.0 5.9 5.5 5.2 5.6 5.3 5.2 5.2

Conductivity(µs) 20.8 20.6 38.7 32.8 87.7 80.2 96.4 91.5 65.7 64.2 80.9 79.6 75.3 73.2 56.7 54.8 67.9 65.8 89.5 85.4

Organic Carbon (%) 0.36 0.27 0.67 0.43 1.23 0.54 1.18 0.48 0.45 0.26 1.34 0.61 1.21 0.72 1.06 0.56 0.67 0.32 1.71 0.58

Chloride (ppm) 156 152 256 235 672 645 452 423 1027 1021 167 145 144 134 165 123 876 767 721 711

Nitrogen (%) 0.29 0.25 0.25 0.25 0.38 0.38 0.39 0.37 0.29 0.28 0.25 0.24 0.24 0.26 0.24 0.30 0.30 0.39 0.27 0.29

Phosphate (ppm) 0.50 0.30 1.90 1.70 3.40 2.65 4.60 3.60 1.90 1.70 2.80 1.77 6.10 4.30 8.1 6.10 2.98 2.42 6.30 4.20

ECEC meq/100g 5.82 5.70 7.20 7.21 6.63 6.60 5.70 5.65 7.24 7.20 6.90 6.95 7.24 7.30 5.60 5.62 5.81 5.78 6.21 6.10

THC (ppm) 0.68 0.71 2.19 3.34 3.46 4.34 5.27 5.34 1.67 1.87 2.87 3.12 4.12 4.15 4.14 4.23 5.39 5.67 5.63 5.67

Metal

Lead (ppm) <0.001 <0.001 0.03 0.02 0.01 0.002 0.10 0.005 <0.001 <0.001 0.002 0.001 0.05 0.03 0.04 0.03 0.02 0.01 0.01 0.001

Mercury (ppm) <0.001 <0.001 0.03 0.02 0.01 0.01 0.04 0.02 0.05 0.03 <0.001 <0.001 0.03 0.02 0.05 0.04 <0.001 <0.001 0.02 0.01

Iron (ppm) 67 69 38.12 40.12 189 194 894 905 315 338 397 490 783 812 681 776 456 476 242 267

Zinc (ppm) 0.01 0.01 0.50 0.36 0.02 0.01 0.01 0.01 0.26 0.19 0.40 0.20 0.09 0.07 0.05 0.04 0.50 0.03 0.07 0.06

Nickel (ppm) 0.19 0.21 0.23 0.21 <0.01 <0.01 0.12 0.16 <0.01 <0.01 0.14 0.15 0.05 0.06 0.06 0.07 0.13 0.15 0.24 0.25

Vanadium (ppm) 0.32 0.22 0.12 0.15 0.22 0.20 <0.01 <0.01 0.05 0.03 0.07 0.09 0.21 0.23 0.15 0.10 0.30 0.24 0.33 0.30

Chromium (ppm) 0.37 0.34 0.65 0.70 0.38 0.41 3.91 0.40 7.11 7.14 6.13 6.23 1.65 1.75 0.61 0.61 0.46 0.87 1.45 1.46

Cadmium (ppm) <0.001 0.001 0.001 0.002 0.003 0.004 <0.001 0.01 0.005 0.008 <0.001 <0.001 <0.001 0.001 <0.001 0.001 0.001 0.002 <0.001 0.001

Manganese (ppm) <0.005 0.005 <0.005 0.006 0.006 0.007 0.008 0.005 <0.005 <0.005 0.008 0.006 0.007 0.005 <0.005 <0.005 0.008 0.006 0.007 0.008

SPDC Appendix


253

Cu (ppm) <0.01 <0.01 0.05 0.03 0.02 0.01 0.04 0.02 <0.01 <0.01 0.05 0.04 0.03 0.02 <0.01 <0.01 0.01 <0.01 0.01 0.01

SPDC Appendix


253

Table 4.3 contd.

Sample code

Parameters

SS 11

SS 12

SS 13

SS 14

SS 15

SS 16

SS 17

SS18

SS 19

SS 20

Depth 0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

0-15cm 15-

30cm

Physico-chemical

PH 5.2 5.1 5.6 5.3 5.4 5.2 5.0 5.0 4.8 4.7 5.3 5.2 6.0 5.9 5.5 5.4 5.6 5.3 5.2 5.2

Conductivity(µs) 20.9 20.4 29.8 27.2 76.3 60.2 94.8 90.3 63.6 55.7 81.7 76.9 77.2 64.3 56.7 50.3 66.8 53.8 90.3 76.8

Organic Carbon (%) 0.36 0.27 0.67 0.43 1.23 0.54 1.18 0.48 0.45 0.26 1.34 0.61 1.21 0.72 1.06 0.56 0.67 0.32 1.71 0.58

Chloride (ppm) 149 150 256 234 672 634 452 423 1027 987 167 156 144 146 167 163 876 873 721 712

Nitrogen (%) 0.25 0.26 0.39 0.33 0.37 0.38 0.29 0.28 0.32 0.35 0.37 0.35 0.39 0.39 0.29 0.30 0.33 0.30 0.34 0.37

Phosphate (ppm) 0.51 0.32 1.90 1.73 3.42 2.64 4.60 3.65 1.90 1.75 1.80 1.77 6.10 4.38 7.20 6.15 2.88 2.47 5.89 4.23

ECEC meq/100g 5.45 5.20 7.20 7.11 6.53 5.90 5.80 5.45 7.34 7.21 6.87 6.72 7.22 7.10 5.70 5.92 5.81 5.70 6.30 6.10

THC (ppm) 0.73 0.75 2.19 1.80 3.36 2.46 4.27 4.34 1.64 1.34 2.85 2.32 7.10 6.24 6.13 4.23 4.09 4.12 2.63 2.25

Metal

Lead (ppm) <0.001 <0.001 0.03 0.01 0.01 0.02 0.010 0.010 <0.001 0.001 0.002 0.003 0.05 0.06 0.04 0.03 0.02 0.01 0.02 0.001

Mercury (ppm) <0.001 0.001 0.03 0.02 0.01 0.01 0.04 0.03 0.05 0.04 <0.001 <0.001 0.03 0.01 0.05 0.05 <0.001 <0.001 0.02 0.01

Iron (ppm) 67 70 39.12 45.90 190 196 876 895 320 334 386 423 743 814 687 697 456 460 246 257

Zinc (ppm) 0.02 0.01 0.50 0.32 0.12 0.01 0.01 0.01 0.20 0.18 0.40 0.30 0.09 0.08 0.05 0.04 0.05 0.04 0.06 0.06

Nickel (ppm) 0.17 0.15 0.22 0.24 <0.01 <0.01 0.14 0.15 <0.01 <0.01 0.13 0.10 0.04 0.05 0.06 0.05 0.13 0.12 0.24 0.22

Vanadium (ppm) 0.33 0.21 0.12 0.10 0.25 0.20 0.01 <0.01 0.04 0.02 0.05 0.03 0.21 0.20 0.12 0.10 0.25 0.23 0.31 0.32

Chromium (ppm) 0.36 0.32 0.64 0.62 0.37 0.35 3.95 3.87 7.19 7.09 6.16 5.89 1.69 1.43 1.32 1.20 0.46 0.42 1.45 1.23

Cadmium (ppm) <0.001 <0.001 0.001 <0.001 0.003 0.001 <0.001 <0.001 0.005 0.003 <0.001 <0.001 <0.001 <0.001 <0.001 <0.001 0.001 <0.001 <0.001 <0.001

Manganese (ppm) <0.005 <0.005 <0.005 <0.005 0.006 <0.005 0.007 0.005 <0.005 <0.005 0.008 0.006 0.007 0.005 <0.005 <0.005 0.008 0.006 0.005 0.003

Cu (ppm) 0.01 <0.01 0.03 0.05 0.02 0.04 0.04 0.03 <0.01 <0.01 0.05 0.04 0.03 0.04 <0.01 0.03 0.01 <0.01 0.01 0.02

SPDC Appendix


Table 4.3c: Texture Analysis of Soils from Benisede field

S/NO SOIL SAMPLE

IDENTITY (cm)

CLAY

SILT

SAND Textural class

% % %

1 SS1 (0-15) 17.2 11.2 71.6 S

2 SS1 (15-30) 10.5 21.7 67.8 S

3 SS2 (0-15) 8.4 24.9 66.7 S

4 SS2 (15-30) 9.2 25.2 65.6 S

5 SS5 (0-15) 8.7 23.9 67.4 SL

6 SS5 (15-30) 8.6 24.7 66.7 SCL

7 SS6 (15-30) 9.3 26.3 64.4 SL

8 SS6 (15-30) 8.7 26.1 65.2 SL

9 SS8 (0-15) 10.1 17.4 72.5 SL

10 SS8 (0-30) 13.5 20.7 65.8 SL

11 SS9 (0-15) 8.7 20.6 70.7 SL

12 SS9 (0-30) 3.4 8.5 88.1 S

13 SS12 (0-15) 11.2 22.2 66.6 S

14 SS12 (0-30) 8.3 23.2 68.5 SL

15 SS18 (0-15) 5.6 21.9 72.5 SL

16 SS18 (0-30) 8.3 21.2 70.5 SCL

17 SS23 (0-15) 14.2 20.3 65.5 SCL

18 SS18 (0-30) 10.2 24.4 65.4 SCL

19 SS21 (0-15) 12.9 21.8 65.3 SCL

20 SS21 (0-30) 13.2 18.6 68.2 SCL

S = Sand

SL = Sandy Loam.

SCL = Sandy Clay Loam

SPDC Appendix


TABLE 4.4: PLANT TISSUE (MATURE LEAVES) ELEMENTAL/NUTRIENT COMPOSITION OF THE COMMONEST PLANT SPECIES

WITHIN BCA FDP AREA

Sample Identity N

ppm

P

%

K

ppm

Ca

ppm

Mg

ppm

Na

ppm

Fe

ppm

Mn

ppm

Zn

ppm

Cu

ppm

Cr

ppm

Cd

ppm

Ni

ppm

V

ppm

Pb ppm Hg

ppm

Cyrtospermum

senegalense

2.15 0.19 1.30 2.52 0.06 1.33 76.65 2.25 5.21 1.45 1.31 0.15 3.05 0.71 1.64 0.01

Saciolepis sp. 2.05 0.21 1.27 1.54 0.04 1.05 7.21 0.68 1.41 5.26 0.80 0.12 3.22 0.61 0.63 0.01

Eichhornea

crassipes

2.19 0.18 1.25 3.08 0.32 1.76 45.5 1.20 5.96 7.41 0.88 0.27 0.06 0.38 1.09 0.01

Xanthosoma sp. 2.00 0.25 1.24 3.91 0.51 2.15 35.5 1.23 4.37 2.40 1.20 0.14 1.07 0.61 1.72 0.01

Saciolepis sp. 2.24 0.22 1.28 0.71 0.02 1.43 16.29 0.48 1.26 3.11 1.04 0.15 0.04 0.53 1.21 0.01

Alchornea

cordifolia

2.24 0.18 1.23 1.96 0.03 0.17 27.75 0.93 2.67 3.82 0.72 0.43 0.97 0.46 1.30 0.01

Saciolepis sp. 2.21 0.29 1.26 1.41 0.03 1.60 24.55 0.84 1.99 3.82 0.63 0.11 3.49 0.76 1.42 0.01

Alchornea

cordifolia

2.22 0.19 1.23 1.89 0.03 1.98 33.38 0.88 1.41 7.65 1.04 0.15 0.11 0.84 1.65 0.01

Musa

paradisiac

a

2.19 0.23 1.27 1.57 0.25 2.16 11.3 0.86 1.54 20.53 2.37 0.16 1.50 0.53 1.51 0.01

SPDC Appendix


Table 4.5: Physico-Chemical Characteristics of Water

Sample code

Parameters

WS 1

WS 2

WS 3

WS 4

WS 5

WS 6

W S7

WS 8

Physico-chemical

pH 5.7 5.9 6.0 6.2 5.8 6.5 6.1 6.2

Turbidity (NTU) 2.8 3.4 2.2 20.1 23.2 8.9 45.1 28.7

Temperature (oC) 28.4 28.5 30.4 29.2 21.8 33.4 32.2 30.1

Dissolved oxygen (mg/l) 4.48 5.10 5.9 4.43 4.45 5.09 5.06 5.03

Conductivity (mS/cm) 26.7 77.6 30.2 99.2 90.4 28.4 30.1 55.6

Total Dissolved Solid (mg/l) 37.3 38.2 41.8 52.7 60.8 90.1 48.6 94.0

Bicarbonate 0.57 0.69 1.81 0.60 0.91 1.74 2.91 3.21

Chloride 26.8 99.2 96.1 30.1 43.8 44.7 45.6 6.3

Na+ (mg/l) 5.70 5.74 3.82 2.51 4.68 2.69 5.31 3.09

K+(mg/l) 1.90 5.91 8.70 2.93 1.85 8.11 2.15 7.19

Ca++(mg/l 26.91 23.12 5.67 10.83 2.17 4.89 7.50 27.19

Mg++(mg/l) 1.93 4.31 1.83 1.95 2.13 2.58 3.61 4.34

THC (mg/l) <0.50 <0.50 <0.50 <0.50 <0.50 <0.50 <0.50 <0.50

COD (mg/l) 4.8 14.5 3.9 9.11 12.4 15.3 5.7 6.9

BOD 0.87 0.93 0.86 0.87 1.02 1.09 0.93 0.97

Metals

Lead (mg/l) 0.02 0.05 0.09 0.01 0.73 <0.01 <0.01 0.04

Mercury (mg/l) <0.01 <0.01 <0.01 <0.01 <0.01 <0.01 <0.01 <0.01

Iron (mg/l) 48 30 23 56 84 27 78 90

Zinc (mg/l) 1.34 1.22 10.81 9.73 8.91 12.12 7.97 5.79

Nickel (mg/l) 0.08 1.09 0.87 0.09 2.10 2.06 0.08 2.01

Vanadium (mg/l) 0.17 0.15 0.12 0.16 <0.01 0.19 0.8 0.11

Chromium (mg/l) 0.35 0.91 0.25 2.11 2.05 0.38 0.78 0.87

Manganese 12 20 31 16 19 21 15 34

Cadmium 0.09 0.03 0.05 <0.01 0.06 0.07 0.08 0.06

Copper 2.67 1.02 1.45 3.41 3.25 2.89 1.07 1.11

SPDC Appendix


Table 4.5 contd.

Sample code

Parameters

WS9

WS10

WS11

WS12

WS 13

WS14

WS 15

Physico-chemical

pH 5.9 6.2 6.4 5.9 5.8 5.9 6.1

Turbidity (NTU) 12.6 34 2.1 23.6 2.1 34.8 2.20

Temperature (oC) 28.5 29.2 30.3 32.3 29.4 28.8 31.4

Dissolved oxygen (mg/l) 4.56 4.63 4.56 4.89 4.47 5.09 5.07

Conductivity (mS/cm) 29.4 32.7 32.2 29.7 36.2 74.6 31.2

Total Dissolved Solid (mg/l) 30.5 35.7 38.9 45.9 37.4 42.2 84.8

Bicarbonate 0.67 1.63 2.16 0.93 0.56 0.89 1.21

Chloride 56.2 60.1 33.7 35.9 26.8 99.2 96.1

Na+ (mg/l) 4.70 3.87 4.12 5.01 5.72 5.63 3.85

K+(mg/l) 6.12 5.19 8.30 1.95 1.95 5.93 8.74

Ca++(mg/l 20.10 15.34 7.89 6.90 4.91 23.13 5.69

Mg++(mg/l) 3.90 3.11 1.97 2.56 1.96 4.34 1.87

THC (mg/l) <0.50 <0.50 <0.50 <0.50 <0.50 <0.50 <0.50

COD (mg/l) 6.7 13.6 12.9 5.6 4.5 14.3 3.7

BOD 1.20 1.05 0.86 0.85 0.93 0.92 0.88

Metals

Lead (mg/l) 0.07 0.08 0.81 0.90 0.03 0.08 0.09

Mercury (mg/l) <0.01 <0.01 <0.01 <0.01 <0.01 <0.01 <0.01

Iron (mg/l) 76 46 57 45 56 31 25

Zinc (mg/l) 4.96 1.69 1.45 1.67 1.37 1.22 11.81

Nickel (mg/l) 1.18 1.90 2.07 1.87 0.08 1.17 0.81

Vanadium (mg/l) <0.01 <0.01 <0.01 <0.01 0.18 0.19 0.13

Chromium (mg/l) 0.34 1.97 2.06 0.67 0.35 0.91 0.29

Manganese 19 28 23 30 15 22 35

Cadmium <0.01 <0.01 0.01 0.08 0.07 0.04 0.06

Copper 2.15 2.78 3.32 1.19 2.63 1.12 1.46

SPDC Appendix


Table 4.5 contd.

Sample code

Parameters

WS 16

WS 17

WS 18

WS 19

WS 20

Physico-chemical

pH 6.5 6.8 6.5 6.1 6.3

Turbidity (NTU) 27.1 56 28.9 45.1 28.9

Temperature (oC) 28.2 28.7 31.4 33.2 29.1

Dissolved oxygen (mg/l) 4.42 4.49 5.07 5.06 5.04

Conductivity (mS/cm) 99.2 91.4 28.4 30.1 59.6

Total Dissolved Solid (mg/l) 52.9 64.8 110.8 48.2 94.1

Bicarbonate 0.65 1.91 1.94 2.31 3.31

Chloride 30.1 43.8 44.7 45.6 6.3

Na+ (mg/l) 2.56 4.72 2.91 5.32 3.19

K+(mg/l) 6.91 1.87 8.14 2.14 7.29

Ca++(mg/l 11.83 12.67 4.87 7.54 27.29

Mg++(mg/l) 2.91 2.17 2.58 3.62 4.32

THC (mg/l) <0.50 <0.50 <0.50 <0.50 <0.50

COD (mg/l) 9.13 13.4 15.3 4.7 6.7

BOD 0.89 1.21 1.19 1.93 0.97

Metals

Lead (mg/l) 0.01 0.73 <0.01 <0.01 0.04

Mercury (mg/l) <0.01 <0.01 <0.01 <0.01 <0.01

Iron (mg/l) 59 86 29 76 91

Zinc (mg/l) 10.53 8.91 12.10 7.97 5.77

Nickel (mg/l) 0.16 2.09 2.12 0.09 2.02

Vanadium (mg/l) 0.17 <0.01 0.16 0.16 0.11

Chromium (mg/l) 2.11 2.09 0.48 0.72 0.85

Manganese 18 12 27 32 29

Cadmium 0.01 <0.01 0.02 0.08 0.07

Copper 3.40 3.27 2.87 1.42 1.13

SPDC Appendix


Table 4.6: Physico-Chemical Characteristics of Sediment

Sample code

Parameters

Sed 1

Sed 2

Sed 3

Sed 4

Sed 5

Sed 6

Sed 7

Sed8

Sed9

Sed10

Physico-chemical

pH 6.0 6.2 5.4 5.7 5.9 6.1 5.5 5.8 6.3 5.3

THC(mg/g ) 2.0 3.5 2.5 3.7 7.6 8.2 7.6 2.9 7.3 3.3

Nitrate (ppm) 0.02 0.01 0.93 0.78 0.45 2.09 2.71 0.06 0.67 1.21

Total Nitrogen (mg/kg) 0.19 0.17 0.19 0.15 0.14 0.21 0.28 0.18 0.19 0.30

Phosphate (mg/kg) 0.7 0.6 0.4 1.6 1.9 2.8 6.1 0.8 2.9 6.0

Ca+ (mg/kg) 2.98 3.11 7.8 9.2 9.7 8.6 11.01 4.23 5.87 9.67

Na+ (mg/kg) 0.07 0.02 0.6 0.5 0.09 0.72 0.61 0.08 0.09 0.63

Mg+ (mg/kg) 0.26 0.19 5.56 7.0 0.37 0.28 10.31 0.36 0.43 1.78

K+ (mg/kg) 0.71 6.11 4.67 1.15 3.98 6.23 5.19 0.67 0.45 6.11

Metal

Lead (mg/kg) <0.001 0.03 0.01 0.05 <0.001 0.002 0.05 0.04 0.02 0.01

Iron (mg/kg) 67 78 109 134 112 89 103 68 69 142

Chromium (mg/kg) 0.39 0.65 0.40 3.91 7.11 6.13 1.65 0.61 0.46 1.45

Vanadium (mg/kg) 0.32 0.12 0.22 <0.01 0.05 0.07 0.21 0.12 0.26 0.33

Zinc (mg/kg) 3.58 26.3 19.4 3.51 7.89 11.5 5.65 3.67 22.3 12.4

Nickel (mg/kg) 0.19 0.23 2.76 2.90 3.18 4.42 2.38 1.34 3.16 1.25

Cu (mg/kg) 2.36 2.34 6.35 7.12 6.45 3.41 2.34 7.11 4.17 3.87

Mercury (mg/kg) <0.001 0.03 0.02 0.01 0.01 <0.001 0.02 0.03 <0.001 0.03

Manganese (mg/kg) 56 70 67 86 100 63 79 58 86 91

SPDC Appendix


Sample code

Parameters

Sed

11

Sed

12

Sed

13

Sed

14

Sed

15

Sed

16

Sed

17

Sed

18

Sed

19

Sed

20

Physico-chemical

pH 6.1 5.2 5.3 5.6 6.0 6.2 6.1 5.6 5.4 6.0

THC (mg/g ) 2.2 3.6 2.6 3.9 7.5 8.2 7.5 2.7 7.4 3.5

Nitrate (ppm) 0.04 0.01 0.13 0.75 0.44 2.08 2.70 0.16 0.61 1.20

Total Nitrogen (mg/kg) 0.28 0.25 0.22 0.19 0.29 0.32 0.19 0.21 0.20 0.19

Phosphate (mg/kg) 0.7 0.6 0.6 1.2 1.7 2.7 6.0 1.8 2.2 6.1

Ca+ (mg/kg) 2.97 3.23 7.5 9.7 9.3 8.5 11.11 4.56 5.12 9.34

Na+ (mg/kg) 0.09 0.08 0.07 0.52 0.09 0.72 0.65 0.09 0.08 0.63

Mg+ (mg/kg) 0.23 2.19 5.16 7.6 1.37 0.22 10.32 3.36 1.43 1.78

K+ (mg/kg) 0.72 6.13 4.65 1.16 3.94 6.21 5.18 0.67 0.41 6.15

Metal

Lead (mg/kg) <0.001 0.01 0.002 0.01 <0.001 0.002 0.05 0.04 0.02 0.01

Iron (mg/kg) 66 72 119 132 135 87 113 68 76 132

Chromium (mg/kg) 0.39 0.61 0.33 3.92 7.20 6.17 1.64 0.62 1.46 2.45

Vanadium (mg/kg) 0.31 0.16 0.22 <0.01 0.21 0.07 0.25 0.19 0.24 0.38

Zinc (mg/kg) 7.51 26.7 19.2 3.41 9.81 11.9 10.76 9.67 22.1 12.9

Nickel (mg/kg) 0.19 0.21 2.72 2.93 3.16 4.41 2.31 1.12 3.15 1.27

Cu (mg/kg) 2.35 3.31 6.36 7.10 6.42 5.43 2.36 7.12 4.15 3.17

Mercury (mg/kg) <0.001 0.03 0.01 0.01 0.02 <0.001 0.01 0.01 <0.001 0.02

Manganese (mg/kg) 58 72 61 88 90 67 76 54 81 92

SPDC Appendix


Table 4.7: Summary of Heterotrophic and Petroleum Degrading bacterial count of Soil

Composite

Sample

Heterotrophic

bacterial counts

cfu/g soil

Petroleum

Degrading

bacterial count

cfu/g soil

Percentage

Degraders

(%)

Bacterial isolates

SS 1 4.3 x 108 2.4 x 10

6 0.56 Proteus sp Pseudomonas sp

SS 2 3.5x 107 3.1 x 10

5 0.89 Micrococcus sp Bacillus sp

SS 3 4.2 x 108 3.1 x 10

6 0.74 Pseudomonas sp Bacillus sp

SS 4 3.5 x 108 3.5 x 10

5 0.10 Pseudomonas sp

SS 5 4.1x 108 4.6 x 10

4 0.01 Escherichia sp

SS 6 5.7x 108 4.7 x 10

6 0.82 Klebsiella sp

SS 7 4.8 x 106 4.2 x 10

4 0.88 Escherichia.coli, Proteus sp

SS 7 3.8 x 108 3.6 x 10

6 0.95 Pseudomonas sp

SS 8 3.6x 1010

4.8 x 107 0.13 Micrococcus sp

SS 9 2.6x 109 2.7 x 10

7 1.04 ESCHERICHIA .COLI,

HAFNIA

SS 10 3.1x 108 2.6 x 10

5 0.08 Micrococcus sp, Bacullus sp

SS 11 6.5 x 107 3.5 x 10

5 0.54 Klebsiella sp, Bacillus sp

SS 12 4.3 x 107 1.3 x 10

4 0.03 Micrococcus sp

SS 13 4.4 x 108 5.6 x 10

6 1.27 Proteus sp

SS 14 5.8x 109 2.4 x 10

6 0.04 Proteus sp

SS 15 5.3 x 108 2.4 x 10

5 0.05 Microcroccus sp

SS 16 4.9 x 107 2.1 x 10

4 0.04 Micrococcus sp

SS 17 8.7 x 108 1.0 x 10

4 0.00 Escherachia sp

SS 18 2.5 x 108 2.4 x 10

5 0.10 Bacillus sp

SS 19 2.1 x 109 1.5 x 10

6 0.07 Bacillus sp

SS 20 1.6 x 106 1.1 x 10

4 0.69 Escherichia sp

SPDC Appendix


Table 4..8 : Summary of heterotrophic and degrading fungal count of Soil

Sample

Code

Heterotrophic

fungi counts

Petroleum

Degrading fungi

Percentage

Degraders (%)

Fungi isolates

SS 1 1.1x 106 1.2 x 103 0.11 Candida sp, Nucor sp

SS 2 2.7 106 3.1 x 104 1.15 Cladosporum sp, Candida sp

SS 3 3.4 x 105 3.7 x 103 1.09 Cladosponim sp

SS 4 7.2 x 105 5.8 x 103 0.81 Penicillium sp


SS 6 3.5 x 106 1.2x 104 0.34 Aspergillus sp

SS 7 6.3 x 106 2.1 x 104 0.33 Candida sp, Aspergillus sp

SS 8 1.4 x 105 6.8 x 102 0.49 Candida sp

SS 9 2.3 x 108 2.9 x 106 1.26 Mucor sp, Saccharomyces sp

SS 10 6.5x 105 1.5 x 103 0.23 Candida sp

SS 11 8.0 x 104 4.0 x 102 0.50 Aspergilus sp

SS 12 4.5 x 107 2.1 x 105 0.47 Candida sp; Nucor sp

SS 13 2.2 x 105 1.0x 103 0.45 Aspergillus sp, Candida sp

SS 14 4.8 x 105 2.3 x 102 0.05 Cladosporum sp, Candida sp

SS 15 1.2 x 106 1.1 x 104 0.92 Candida sp, Mucor sp

SS 16 3.5x 105 2.3 x 103 0.66 Aspergillus sp, Mucor sp

SS 17 4.5 x 104 1.8 x 102 0.40 Candida sp; Mucor sp

SS 18 1.3 x 105 5.1 x 102 0.39 Cladasporum sp


SS 20 2.5 x 105 1.6x 103 0.64 Candida sp

SPDC Appendix


Table 4.9: Microbial Analysis of Benisede Water Sample (Bacteria)

Sampling

Location

Heterotrophic

bacterial count

(cfu/ml x106)

Petroleum

degraders

(cfu/ml x104)

% Degraders Bacterial isolates

WS 1 10.3 2.1 0.20 Bacillus sp

Pseudomonas sp

WS 2 8.5 0.6 0.07 Staphylococcus sp


WS 4 5.5 0.2 0.04 Pseudomonas



WS 7 6.1 0.4 0.07 Pseudomonas sp

WS 8 7 0.4 0.06 Bacillus sp

WS 9 9.1 0.4 0.04 Staphylococcus sp



WS 12 7.8 0.5 0.06 Escherichia sp




WS 16 5.5 0.4 0.07 Escherichia sp




WS 20 5.1 0.1 0.02 Pseudomonas

SPDC Appendix


Table 4. 10: Microbial Analysis of Benisede Water Sample (Fungi)

Sampling

Location

Heterotrophic

Fungal count

propagules (cfu/ml

x105)

Petroleum

degraders

Propagules (cfu/ml

x103)

% Degraders Fungal isolates

WS 1 8.2 2 0.24 Mucor sp

WS 2 5.3 0 0.00 Penicillium sp

WS 3 5.4 1.2 0.22 Mucor sp

WS 4 5.1 0 0.00 Cladosporum sp


WS 6 4.5 0 0.00 Mucor sp

WS 7 3.6 1 0.28 Mucor sp

WS 8 3.1 1.2 0.39 Penicillium sp

WS 9 5 0 0.00 Mucor sp


WS 11 5.2 1.2 0.23 Mucor sp

WS 12 5 0 0.00 Cladosporum sp


WS 14 4.6 0 0.00 Mucor sp

WS 15 3.6 1 0.28 Mucor sp

WS 16 3.2 1.2 0.38 Penicillium sp


WS 18 4.8 0.8 0.17 Cladosporum sp

WS 19 5.3 0 0.00 Candida sp

WS 20 5.6 0 0.00 Mucor sp, Candida

sp

SPDC Appendix


Table 4.11: Microbial Analysis of Sediment sample (Bacteria)

Sampling

Location

Heterotrophic

bacterial count

cfu/g soil x107

Petroleum

degraders cfu/g

soil x105

% Degraders Bacterial isolates

Sed 1 11.8 1.3 0.11 Staphylococcus

sp, Bacillus sp.

Sed 2 18.5 3.2 0.17 Pseudomonas sp


Sed 4 16.5 2.5 0.15 Bacillus sp


Sed 6 18.4 2.4 0.13 Pseudomonas sp;

Bacillus sp.

Sed 7 23.1 2.5 0.11 Bacillus sp.


sp.

Sed 9 20.7 2.1 0.10 Bacillus sp.

Sed 10 18.5 0.4 0.02 Escherichia sp,

Bacillus sp

Sed 11 18.6 2.1 0.11 Pseudomonas sp.

Sed 12 19.8 2.3 0.12 Bacillus sp.

Sed 13 23.4 2.4 0.10 Bacillus sp

Pseudomonas sp.

Sed 14 22.5 0.17 0.01 Bacillus sp,

Pseudomonas sp

Sed 15 13.7 2.7 0.20 Pseudomonas sp;

Sed 16 22.5 2.2 0.10 Bacillus sp.


sp.

Sed 18 14.9 2.3 0.15 Bacillus sp.

Sed 19 21.5 3 0.14 Escherichia sp.

Sed 20 17.2 3.2 0.19 Pseudomonas sp.

SPDC Appendix


TABLE 4.12: MICROBIAL ANALYSIS OF SEDIMENT SAMPLES (FUNGI)

Sampling

Location

Heterotrophic

bacterial count

propagules /g soil

x106)

Petroleum degraders

Propagules/g soil

x104)

% Degraders Fungal isolates

Sed 1 2.55 1.2 0.47 Penicillium sp.

Sed 2 5.23 2.1 0.40 Mucor sp.

Penicillium,sp

Sed 3 3.45 2.5 0.72 Mucor sp.

Sed 4 4.13 2.1 0.51 Cladosporum sp.

Sed 5 3.21 1.3 0.40 Mucor sp.

Sed 6 3.56 2.7 0.76 Mucor sp.

Sed 7 3.12 1.8 0.58 Penicillium,sp.


Sed 9 3.18 1.6 0.50 Mucor sp,

Penicillium sp.


Sed11 2.97 1.3 0.44 Cladosporum sp.

Sed12 4.17 2.4 0.58 Mucor sp.

Penicillium, sp

Sed 13 5.24 1.9 0.36 Penicillium,sp.

Sed 14 3.65 2.6 0.71 Rhizopus,

Penicillium sp.


Sed 16 3.25 1.3 0.40 Mucor sp.


Sed 18 3.23 2.1 0.65 Cladosporum sp.

Sed 19 3.12 1.6 0.51 Mucor sp.

Sed 20 4.16 1.7 0.41 Mucor sp.

Penicillium, sp

SPDC Appendix


CHECK LIST OF REVIEW PANEL COMMENTS ON THE EIA OF BENISEDE CATCHMENT AREA PHASE II

FIELD DEVELOPMENT PLAN

S/N

Review panel comments

How Addressed

Where (Chapter/Page)

1 EXECUTIVE SUMMARY

The Executive Summary appeared to be either lacking or rather frugal

on some basic information such as project schedule, project

alternatives, decommissioning/Abandonment and summary of

findings on baseline studies. It did not give a complete picture of what

was done and what was found.

Project schedule and

alternatives, decommissioning

and abandonment and more

baseline information included

in the executive summary

Executive summary,

Page 3 of 11 and 6 of 11

2 The report could do more to expantiate on the reported North-South

Wind.

North-South wind further

explained

Executive summary,

Page 4 of 11

3 Turbidity values are quoted in the Executive Summary and main

reports, but the abbreviation (NTU) was not explained in the list of

Acronyms & Abbreviations.

Abbreviation explained List of Abbreviations and

Acronyms, Page xv

4 Local Government Area mentioned in the report should be the

federally recognized LGAs.

LGA list reviewed Ex. Sum. Page 7 of 11,

chapter 4 page 30 of 44

and page 34 of 44

5 The inclusion of a geological map is commendable, however, there are

a few mis-representations in the map viz.

(a) Niger Delta Basin has no age within the legend

(b) The project area indicated covers Okigwe, Enugu and

Onitsha as against the Niger Delta.

(c) Bight of Bonny, not properly marked.

Age stated in legend.

Map is geologic map of

Nigeria and not that of study

area only.

Bight of Bonny correctly

marked.

Appendix I, Geologic

map

1

CHAPTER ONE

The statement that 9 wells shall be drilled (para 1 page 1 of 11) with

Statements reconciled

Chapter 1 page 1 of 15

SPDC Appendix


the statement in para 1 of Exec. Summary where it was stated that 10

wells shall be drilled should be reconciled.

and Executive summary

page 1 of 11

2 Para 1 (same page) states that 21 wells are tied to the Benisede F/S

and the last paragraph states that there are 37 wells with 22 producing.

Please reconcile.

Number of well reconciled Chapter 1 page 2 of 15

3 Is there an Agency called Bayelsa State EPA? No: correction effected Chapter 1, Page 4 of 15

4 A major Delta State legislation which relates to this project is the State

Forestry Law. Summary of the provisions of this law should be

included in the report.

Forestry law included Chapter 1, Page 13 of 15

5 Decree and Acts are used interchangeable in the report. By the 4th

Republic 1999 Constitution of the Federal Republic of Nigeria, all

Decrees are now Acts of Parliaments.

Decrees replaced with Act Chapter 1, pages 6 of 15

1

CHAPTER TWO PROJECT JUSTIFICATION

The Section on Project Alternatives should be re-written as the

scenarios/alternatives have been muddled together. E.g. Section 2.6

mentioned 3 scenarios, whereas Table 2.1 listed only two. The

following scenarios are omitted in Table 2.1 2a, 3, 3eb, 4a, 5a, & 5b.

Project alternatives re-written

to clearly state preferred

alternative

Chapter 2, pages 3 and 4

of 4

2

There is nothing to show the environmental sustainability of scenario

4d in Table 2.1.

Table 2.1 (removed) shows

only economic considerations.

Environmental sustainability

of preferred scenario stated.

Chapter 2, page 4 of 4,

last paragraph

1

CHAPTER THREE

Details of the drilling description indicate that about 13 wells shall be

drilled from Benisede, Akono and Opomoyo. This is at variance with

10 mentioned in the Exec. Summary and Chapter 2.

Number of wells reconciled

Chapter 3, pages 1 and 2

of 36

2

A schematic project schedule using a Gantt Chart would have sufficed

rather than the three line statement in Section 3.15.

Gantt chart of project

schedule included in report

Chapter 3, page 18 of 36

SPDC Appendix


3 The report does not contain a detailed categorization and

characterization of all waste (solid, liquid, gaseous) to be generated.

Waste categorization and

characterization included in

the report

Chapter 8, Section 8.5,

page 5 of 20

4

It also does not present a detailed description of the treatment methods

used beyond a casual reference to the Thermal Desorption Unit (TDU)

at Forcados.

Treatment methods described Chapter 8, pages 6 – 13

of 20

5 On Drilling Waste Management the report stated that “ All wastes that

cannot be re-used or re-cycled will be properly disposed. Waste water-

based mud and brine will be treated at the TDU (Thermal Desorption

Unit) in Forcados Terminal” but no details of the treatment method or

diagram of the Unit was given.

Waste treatment methods

described in details

Chapter 8, pages 6 – 13

of 20

6 The method of final disposal of treated waste was also not given. The

report only stated that it would be “disposed offshore”.

Method of final disposal of

waste given

Chapter 3, Section 3.14,

page 17 of 36 and

chapter 8, page 13 of 20

7 The report lacked details of the biological treatment for sanitary

wastes on the rig.

Sanitary waste treatment

process stated


8 What are the composition and expected volume of the sanitary

wastes?

Composition and composition

of sanitary waste stated


9 What was the expected quantity of spent lube oil and diesel spills for

disposal?

Not estimated

10 The whole section on drilling Waste Management lacks adequate data.

Estimated volume of drilling

and sanitary wastes stated

Chapter 8, pages 5 of 20

and 12 of 20

1 CHAPTER FOUR: DESCRIPTION OF THE ENVIRONMENT

Using Rainfall records of 1961-1990 is rather inappropriate. Drastic

climatic changes have occurred in the last 14 years!

More recent records included

in report

Chapter 4, Pages 3 and 4

of 44, Tables 4.1 & 4.2

SPDC Appendix


2 Table 4.1 should have included data for more recent years (1991-

2003). Table 4.2 did not state the year(s) the data were collected.

Working with 1961-1990 figues for more recent years are available

from the same source (the Federal Department of Meteorological

Services, Oshodi) – is not good enough. The data shown did not

indicate that work was actually done in 2 seasons.

More recent records included

in report.

Year of data collection stated

Chapter 4, Page 3 and 4

of 44, Tables 4.1& 4.2

3 The Land Use Pattern of an area is a major issue in its sustainable

development and thus deserves some attention, it was discussed in

only 7 lines. What is the proportion of the various land uses?. What

percentage of the land is occupied by flow station, pipelines and

wellheads? To report that large expanse of forestland exists in the area

is not enough. What is the percentage of land occupied by the forest?.

The land Use Pattern of the project area should be re-written.

Detailed description of Land

use pattern included.

Chapter 4, section

4.2.5.2,

Page 13 – 16 of 44

4 In the report, the total N of the soils of the area is stated to be 0.077%

for surface soil and 0.065% doe subsurface soils. For such values, all

the plants in the area should be stunted and pale green indicating

evidence of severe Nitrogen deficiency. Values of N for similar

ecosystems are 0.23-0.59 for top soil substance soils in heavily

leached and cultivated sites. The N content data of this report should

be re-investigated against the background that species diversity and

abundance is an indicator parameter for monitoring in the EMP.

Nitrogen values reviewed Chapter 4, Page 10 of 44

5 The Statement on page 10 of 10 that Alchornea cordifolia is

characteristic of Niger Delta fresh water swamp vegetation is not

appropriate. This plant occurs freely in all swamp forests of Southern

Nigeria and not exclusive to the Niger Delta.

Statement corrected Chapter 4, Section

4.2.5.1, Page 12 of 44

6 Table 4.6 should be updated with respect to the mesophanerophytes

and Microphanerophytes. SPDC should use the Federal Department of

Forestry Land Use and Vegetation Maps to do the update.

Table updated Chapter 4, Page 15 of 44,

Table 4.6

SPDC Appendix


7 Paragraph 2 of page 15 of 39 stated that vegetation in the BCA FDP

area presents a generally healthy bill but Table 4.8 acknowledges the

prevalence of some diseases in the plant species. The presence of

Sigatoka alone on the plantain already indicated plant ill-health.

Statement re-phrased Chapter 4, Page 18 of 44

8 The main concentrations in plant tissue given as N 0.50, P is 2.04 and

K is 3.78. show subnormal concentration of N and accumulation of P

and K. values of macronutrient concentration in normal leaves of

plants in similar agro ecosystems in Delta State are 2.223 for N, 0.25

for P, 1.27 for K, 0.48 Ca, 0.22 MG, and 0.26 S. again, the plant tissue

analysis should be re-investigated.

Plant tissue analysis reviewed Chapter 4, Page 19 of 44

9 The report only succeeded in telling readers that there are only 5

orders of fishers on the project area. What appeared to the red fish,

knife-fish, trunkfish, moonfish, butterfish, electric fish, etc. a detailed

abundance and diversity shall be a parameter for impact monitoring.

Fisheries studies reviewed,

table 4.10 updated

Chapter 4, Page 24 of 44

10 Socio-economic data especially on the population data on Table 4.11

are obsolete. Current data on Burutu communities are available.

Sources of Tables 4.11 and 4.14 should also be indicated.

Current Data included in

report, source stated


11 Although some health studies were done and reported, there are still

some gaps such as Health risk Assessment, health issues of concern,

major health problems, Available health institutions, Crude death Rate

and the peoples perception of the project.

Gaps on health studies filled Chapter 4, Pages 41- 44

of 44

SPDC Appendix


12 The report devoted only two lines to agriculture by saying that the

locals are mainly subsistence farmers plant cassava, yams, vegetable,

maize and okra. But on page 6 of 6, it is stated that little agriculture

exists and crops such as plantain, cocoyam, and its potentials are

needed in the report.

Details on agriculture

provided

Chapter 4, Pages 7 of 44

Section 4.2.4

13 The data presented is rather old. Although climatic data gives a better

picture when collected over an extensive period, presenting a 14 year

old data is not adequate. Table 4.1

Addressed Chapter 4, Pages 3 and 4

of 44

14 The source of the data in Table 4.1 and 4.2 quoted as the Federal

Department of Meteorological Services shows that the data were not

obtained recently, as this Department was upgraded to an Agency, the

Nigerian Metrological Agency over four years ago.

Addressed Chapter 4, Pages 3 and 4

of 44

15 Where values are recorded as Not Detected (ND) or Below Detection

Limit BDC, the detection limits of the equipment used should be

stated. (eg. VOCs, pg. 4 of 3a).

Detection limits provided in

the methodology

Appendix III

16 The 2.5% growth rate in doubted, except full explanation could be

advanced for the population figures quoted.

1991 census figures and 1996

projection used


17 Why is the 1991 Census figure for, Ojobo not available? How can an

effective and acceptable objective evaluation, prediction on the project

impact on the socio-economic setting of the people be carried out

without the base population figure?

1991 census figure for Ojobo

included

Chapter 4 , page 31 of 44

18 Ojobo community appears to the most populated amongst the host

communities.

No: Ojobo is 3rd

most

populated

Chapter 4 , page 31 of 44

19 Tamogbene Community is in Ekeremor LGA of Bayelsa State and not

Burutu LGA.

Corrected Chapter 4 page 34 of 44

SPDC Appendix


20 The number of primary schools in the project area is 11 not 18 and

those for secondary schools is 5 not 8. (chapter 4, page 36)

Corrections effected Chapter 4, Page 39 of 44

21 One would want to know if the concerns of the host community are

wholly accepted. (pages of 3 chapter 5)

As much as possible Chapter 5, page 3 of 3

1 CHAPTER FIVE: CONSULTATION

The Delta State Ministry of Environment was not consulted in this

project. Reference to the DELSEPA is questionable because Delsepa

stopped handling EIAs since 2001. the reference on page 8 of 13 that

the Special Adviser to Governor on Mineral Resources as the one to

handle community issues/conflict shows the level of ignorance and

laziness of the prepares of this EIA, four years after the State Ministry

of Environment was created.

Delta State ministry of

environment consulted during

scoping workshop in

Yenagoa.

Appendix V: Letters of

invitation and scoping

report

2 The Bayelsa State Ministry of Environment was not consulted during

the field data gathering exercise.

Bayelsa State ministry of

environment consulted during

scoping workshop in

Yenagoa.



report

1

CHAPTER SEVEN: IMPACT MITIGATION

Spreading dredge spoils on river banks has enormous adverse effects.

A proper and safe site should be prepared for the storage of dredge

spoils. (Table 7.1)

Noted. Table 7.1 reviewed

Chapter 7, Table 7.1,

page 4 of 8

2 The statement on pages 5 & 6 of Chapter 7 are not adequate. It is

necessary for the report to describe in technical detail the treatment

and/or remediation methods to be used to “manage wastes generated

in accordance with regulatory requirements and standard practices”.

Detailed waste management

methods stated in report

Chapter 8, pages 5 – 13

of 20

SPDC Appendix


1

GENERAL COMMENTS

The Bayelsa and Delta States Ministry of Environment were not

consulted during the preparation of the EIA of this project. Measures

should be taken to address this.

Both Agencies were consulted

during scoping workshop for

the proposed project in

Yenagoa.



report

2 The Political Map of Bayelsa and Fig. 3.0 showing the project area

were not clear enough. The Local Government Areas (Burutu in Delta

State and Opurumor West in Bayelsa) should have been better shown.

The map and/or Fig. 3.0 did not clearly indicate the locations of

Benisede, Akono and Opomoyo Fields and the communities that will

be directly affected by the project activities.

Clearer map and figure used Chapter 3 and Appendix

I

3 No project schedule was given. This should be done. It is not enough

to say that the “project shall be placed on the long-term drilling

sequence in alignment with SS-AGG project and shall be executed

within the 2004-2008 business planning cycle inputs ….”. the

information is necessary in spite of the uncertainties of the Niger

Delta region.

Project schedule provided Chapter 3, page 18 of 36

4 Actual field data for temperature and rainfall were lacking from the

report.

Data provided Chapter 4, Page 5 of 44

5 The numbering of Tables in the report and in the Appendices is

confusing. There should be only one Table 4.1 for instance, not 2

Table 4.1.

Numbering of tables reviewed Whole document

6 Selection and design of access to the well locations to be optimized to

minimize impact on the environment.

Noted

7 It is noted that eleven (11) wells will be completed as horizontal wells

and that adequate care and attention shall be paid to the well trajectory

design and completions.

Noted: Accurate well

description and number stated

Chapter 3, page 2 of 36,

section 3.4

SPDC Appendix


8 The choice of cluster-drilling rig for the Benisede campaign is

supported as it will minimize impact on the environment whilst

increasing production and providing reduction in well cost.

Noted

9 Procedures for the management and control of drilling wastes are

listed in the EIA, Shell is expected to diligently follow these

procedures during drilling operations.

Noted

10 Well Decommissioning/Abandonment: Chapter 3, Section 3.18; Shell

needs to be more specific on abandonment of wells. The statement

that “wells will be shut-in and suspended till such a time when

sufficient candidates will be available to allow campaign

abandonment” is too open-ended. A target needs to be set for this

activity.

More information provided Chapter 8, page 20 of 20

11 Shell has extensive experience in the construction and operation of

integrated oil and gas processing facility. It is therefore expected that

the Benisede facility shall comply with relevant International,

National and Shell Group Standards as listed in the EIA.

Noted

12 Will the new facility be ISO certified prior to start-up. Yes

13 De-commissioning, abandonment and removal of the existing

Benisede 60MBD when the new 90MBD IFS comes on stream

requires special care to minimize any impact on the environment.

Decommissioning activities

shall meet globally acceptable

standards

14 The following are missing references, - Federal Department of

Meteorological Series (pg. 3 of 39); Chemical Society of Britain 1975

(pg. 9 of 39) line et al, 1997.

References reflected References, page 2 of 6

and 3 of 6

15 The following acronyms were not explained in the list of acronyms

NTU, GFA, STABOR, CMC, ANSI, CPF, OHGP/ESS, ASME, TAO,

MPF etc.

Acronyms have been

explained

List of Abbreviations

and acronyms

SPDC Appendix


TABLE 4.4: PLANT TISSUE (MATURE LEAVES) ELEMENTAL/NUTRIENT COMPOSITION OF THE COMMONEST PLANT SPECIES

WITHIN BCA FDP AREA

Sample Identity N

ppm

P

%

K

ppm

Ca

ppm

Mg

ppm

Na

ppm

Fe

ppm

Mn

ppm

Zn

ppm

Cu

ppm

Cr

ppm

Cd

ppm

Ni

ppm

V

ppm

Pb ppm Hg

ppm

Cyrtospermum

senegalense

2.15 0.19 1.30 2.52 0.06 1.33 76.65 2.25 5.21 1.45 1.31 0.15 3.05 0.71 1.64 0.01

Saciolepis sp. 2.05 0.21 1.27 1.54 0.04 1.05 7.21 0.68 1.41 5.26 0.80 0.12 3.22 0.61 0.63 0.01

Eichhornea

crassipes

2.19 0.18 1.25 3.08 0.32 1.76 45.5 1.20 5.96 7.41 0.88 0.27 0.06 0.38 1.09 0.01

Xanthosoma sp. 2.00 0.25 1.24 3.91 0.51 2.15 35.5 1.23 4.37 2.40 1.20 0.14 1.07 0.61 1.72 0.01

Saciolepis sp. 2.24 0.22 1.28 0.71 0.02 1.43 16.29 0.48 1.26 3.11 1.04 0.15 0.04 0.53 1.21 0.01

Alchornea

cordifolia

2.24 0.18 1.23 1.96 0.03 0.17 27.75 0.93 2.67 3.82 0.72 0.43 0.97 0.46 1.30 0.01

Saciolepis sp. 2.21 0.29 1.26 1.41 0.03 1.60 24.55 0.84 1.99 3.82 0.63 0.11 3.49 0.76 1.42 0.01

Alchornea

cordifolia

2.22 0.19 1.23 1.89 0.03 1.98 33.38 0.88 1.41 7.65 1.04 0.15 0.11 0.84 1.65 0.01

Musa

paradisiac

a

2.19 0.23 1.27 1.57 0.25 2.16 11.3 0.86 1.54 20.53 2.37 0.16 1.50 0.53 1.51 0.01

SPDC Appendix


environmental impact assessment...

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