2011 environmental ogp

8/13/2019 2011 Environmental OGP

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Environmental performance indicators2011 data

Report No. 2011e

October 2012

I n t e r n a t i o n a l A s s o c i a t i o n o f O i l & G a s P r o d u c e r s


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P

ublications

Global experience

Te International Association o Oil & Gas Producers has access to a wealth o technicalknowledge and experience with its members operating around the world in many differentterrains. We collate and distil this valuable knowledge or the industry to use as guidelines

or good practice by individual members.

Consistent high quality database and guidelines

Our overall aim is to ensure a consistent approach to training, management and bestpractice throughout the world.

Te oil & gas exploration & production industry recognises the need to develop consistentdatabases and records in certain fields. Te OGPs members are encouraged to use theguidelines as a starting point or their operations or to supplement their own policies and

regulations which may apply locally.

Internationally recognised source of industry information

Many o our guidelines have been recognised and used by international authorities andsaety and environmental bodies. Requests come rom governments and non-governmentorganisations around the world as well as rom non-member companies.

Disclaimer

hilst every effort has been made to ensure the accuracy o the inormation contained in this publication,neither the GP nor any o its members past present or uture warrants its accuracy or will, regardlesso its or their negligence, assume liability or any oreseeable or unoreseeable use made thereo, whichliability is hereby excluded. onsequently, such use is at the recipients own risk on the basis that any useby the recipient constitutes agreement to the terms o this disclaimer. Te recipient is obliged to inorm

any subsequent recipient o such terms .

Tis document may provide guidance supplemental to the requirements o local legislation. othingherein, however, is intended to replace, amend, supersede or otherwise depart fom such requirements. nthe event o any conflict or contradiction between the provisions o this document and local legislation,

applicable laws shall prevail .

Copyright notice

Te contents o these pages are Te nternational ssociation o il & as roducers. ermission

is given to reproduce this report in whole or in part provided (i) that the copyright o GP and (ii) thesource are acknowledged. ll other rights are reserved. ny other use requires the prior writ tenpermission o the GP.

Tese erms and onditions shall be governed by and construed in accordance with the laws o nglandand ales. isputes arising here fom shall be exclusively subject to the jurisdiction o the courts ongland and ales.


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Environmental perormance indicators2011 data

Report No: 2011e

October 2012


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Te environmental statistics or 2011 were derived rom data provided by the ollowing companies:

Contributing companiesAddaxADNOC

BG

BHP BillitonBP

Cairn EnergyChevron

CNOOC

ConocoPhillips

Dolphin EnergyDONG E&PDragon Oil

Eni E&P Division

ExxonMobilGDF SUEZ

Hess CorporationHusky

INPEX

KosmosKuwait Oil Company

Maersk OilMarathon

MOLNexen

Oil Search

OMVPerenco

PetrobrasPetronas

Premier Oil

P EPQatar Petroleum

Repsol YPFRWE

Shell Companies

StatoilSuncor

alisman Energyotal

ullow

Wintershall


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Environmental performance inindicators 2011 data

OGP

able o contents

Executive summary 1Gaseous emissions ....................................................................................................................................1

Energy consumption.................................................................................................................................1Flaring ......................................................................................................................................................2Aqueous discharges ...................................................................................................................................2Non-aqueous drilling fluids ......................................................................................................................2

Introduction 3

Scope of data submissions 5

Detailed review:

1 Gaseous emissions 71.1 Carbon Dioxide (CO

2

) .......................................................................................................................91.2 Methane (CH

4) ................................................................................................................................10

1.3 Greenhouse Gas (GHG) .................................................................................................................. 111.4 Non-Methane Volatile Organic Compounds (NMVOCs) ...............................................................121.5 Sulphur dioxide (SO

2) ......................................................................................................................13

1.6 Nitrogen oxides (NOX

) ....................................................................................................................14

2 Energy consumption 15

3 Flaring 17

4 Aqueous Discharges 194.1 Quality (oil content) of produced water discharges...........................................................................20

4.2 Quantity of oil discharged in produced water per unit of production ...............................................214.3 Produced Water Injection.................................................................................................................23

5 Non-Aqueous Drilling Fluids 255.1 Non-Aqueous Base Fluid retained on cuttings discharged to sea ......................................................25

6 Spills 276.1 Oil Spills ..........................................................................................................................................27

Appendix A Data tables 33Scope of data submissions .......................................................................................................................33Detailed review.......................................................................................................................................34

1 Gaseous emissions ............................................................................................................................342 Energy Consumption .......................................................................................................................373 Flaring .............................................................................................................................................394 Aqueous discharges ..........................................................................................................................395 Non-Aqueous Drilling Fluids ...........................................................................................................456 Spills ................................................................................................................................................46

Appendix B Glossary 53


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International Association of Oil & Gas Producers

OGP


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OGP

Over the past 13 years, Te International Association o Oil & Gas Producers (OGP) has collectedenvironmental data rom its member companies on an annual basis. Te objective o this programme hasbeen to allow member companies to compare their perormance with other companies in the sector leading,

it is hoped, to improved and more efficient perormance. Te programme also contributes to the industryswish to be more transparent about its operations.

Tis report summarises inormation on exploration and production (E&P) activities carried out bycontributing OGP member companies in 2011. Forty one member companies working in 75 countries

worldwide have submitted data or the report. Tis total includes 5 companies reporting or the first timethis year and all o the 36 companies that contributed data in 2010. Inormation is aggregated at both globaland regional levels and is expressed within 6 environmental indicator categories:

gaseous emissions;

energy consumption;

flaring;

aqueous discharges; discharges o non-aqueous drilling fluids retained on cuttings; and

spills o oil and chemicals.

Tese data represent oil and gas wellhead production o 2,221,462 thousand tonnes, about 32% o 2011global production sales. Tis is a 2% reduction in production compared to 2010. However, regional coverageis uneven, ranging rom almost all known production in Europe to 9% in the Former Soviet Union (FSU).

Gaseous emissions

Releases o gases to the atmosphere are an integral and inevitable part o exploration, production andprocessing operations.

In 2011 participating OGP member companies reported emissions o: 289 million tonnes o carbon dioxide (CO2) equivalent to 133 tonnes o carbon dioxide per thousand

tonnes o hydrocarbon production;

2.6 million tonnes o methane (CH4) equivalent to 1.3 tonnes o methane per thousand tonnes o

hydrocarbon production;

1.0 million tonnes o non-methane volatile organic compounds (NMVOC) equivalent to 0.5 tonneo NMVOC per thousand tonnes o hydrocarbon production;

364 thousand tonnes o sulphur dioxide (SO2) equivalent to 0.2 tonne o SO

2per thousand tonnes o

hydrocarbon production; and

864 thousand tonnes o nitrogen oxides (NOX

) equivalent to 0.4 tonne o NOX

per thousand tonneso hydrocarbon production.

Normalised CH4emissions increased in 2011 by 6% compared with 2010.

Normalised NOX

emissions increased in 2011 by 3% compared with 2010.

Normalised CO2, SO

2and NMVOC emissions remain virtually unchanged compared with 2010.

Energy consumption

Production o oil and gas requires significant quantities o energy or extraction, processing and transport.In many oilfields those energy needs are met by locally produced gas.

In 2011, OGP reporting companies consumed on average 1.6 GigaJoules o energy or every tonne ohydrocarbon produced; a 7% increase compared with the 2010 average. As in previous years, data indicatethat onshore production in 2011 was more energy intensive than offshore production.

Executive summary

Source: BP Energy Review 2012


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OGP

Flaring

Flaring is the controlled burning o hydrocarbons produced in the course o petroleum exploration and

production operations. It includes the controlled and sae burning o gas that or commercial, saety ortechnical reasons is not used or exported.

In 2011, 15.7 tonnes o gas was flared or every thousand tonnes o hydrocarbon produced versus 16.0 tonnesin 2010 and 17.6 in 2009. Reductions in flaring rates are predominantly driven by major inrastructureimprovement projects that increase the capability to inject gas or reservoir maintenance and to deliver gasto markets. Reductions in flaring rates translate to reductions in CO

2and other gaseous emission rates.

Aqueous discharges

Produced water is the most significant water discharge associated with E&P operations. For every tonne

o hydrocarbon produced (including oil, condensates and gas), 0.5 tonne o produced water was dischargedand 1.0 tonne o produced water was re-injected.

Te quality o produced water discharges is measured in terms o oil content. In 2011, the averageconcentration o oil in produced water was 8.1mg/l or onshore discharges and 12.2mg/l or offshoredischarges. When expressed in terms o oil production, overall, these discharges are equivalent to 6.5 tonneso oil or every million tonnes o hydrocarbon produced.

Comparison with 2010 data indicates that the average concentration o oil in produced water dischargeddecreased in 2011 by 10%. Te average quantity o oil discharged per unit o hydrocarbon productiondecreased by 7%.

Non-aqueous drilling fluids

Although most drilling fluids are water-based, some conditions encountered during well dril ling operationsdemand the properties that are only available rom non-aqueous drilling fluids (NADFs). In 2011 reportingcompanies discharged 35,481 tonnes o NADF on drill cuttings. Sixty eight percent o these dischargescontained Group III base fluids and 2% contained Group II fluids. Tere have been no reports o dischargeso Group I fluids since reporting began.

Spills

For the purpose o this report a spill is defined as any loss o containment that reaches the environment (i.e.

is not retained within secondary or other confinement), irrespective o quantity recovered.In 2011, participating OGP member companies reported 3,035 spills greater than 1 barrel in size, resultingin a normalised spill rate o 1.5 spills per million tonnes o hydrocarbon production (1.4 in 2010).

Te reported spills >1 bbl resulted in the release o a total o 15,867 tonnes o oil. Te average quantity ooil spilled per unit o hydrocarbon production has risen to 7.9 tonnes per million tonnes production, 75%higher than the average or 2010but less than hal o the average or 2009.

Deinitions o Group I, II and III base luids are provided in section 5.1 Te eepwater orizon incident was not included in the 2010 report or this report. Te ulti-istrict litigation

beginning in 2012 will address the amount o oil spilled


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OGP

Over the past 13 years, OGP has collected environmental inormation rom its member companies on anannual basis. Te ultimate aim o this effort is to provide a representative statement on the environmental

perormance o the contributing OGP Member companies. Subsidiary objectives are to provide a basis

or individual member companies to compare their environmental perormance, thereby helping them toidentiy areas or improvement and to demonstrate the industrys wish or greater transparency concerningits activities.

Environmental inormation relating to emissions and discharges is collected under the ollowing six categories: gaseous emissions;

energy consumption;

flaring;

aqueous discharges;

discharges o non-aqueous base fluids retained on cuttings; and

spills o oil and chemicals.

Data are collected annually or each o the categories above, on the basis o a set o definitions agreed by theOGP membership. Te definitions are provided via a users guide that is reviewed at regular intervals andupdated to reflect improvements in reporting and to provide additional clarification.

Annual reports o activities in the years 2003 to 2010 and summary reports or activities in 2001 and 2002have been published previously and are available on the OGP website, http://www.ogp.org.uk/publications.

Introduction


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OGP

Scope o data submissions

Forty one OGP member companies reported environmental inormation or, on average, 6 countrieseach. Data rom 75 countries are represented in the report. Te data represent 2,221 million tonnes ohydrocarbon production, approximately equivalent to 32% o 2011 world production as reported in the BP

Statistical Review 2012.

o view the data rom a geographical perspective, 7 regions have been defined.

Production associated with OGP database & 2011 production in BP Statistical Review of World Energy by regionPercentage of known production

0

20

40

60

80

100

120

SouthAmerica

NorthAmerica

Middle EastFSUEuropeAsia/Australasia

Africa

64

43

111

111

9

2320

37

Production figures in this report include oil and gas volumes consumed in operations and thus may exceed sales volumes reported in BP Statistical Review.

North

America

Africa

FSU

Europe

SouthAmerica

Asia/Australia

MiddleEast


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OGP

Tis report only reflects the perormance o the OGP member companies that have provided data. However,where the degree o coverage is highest or example in Europe where a high percentage o hydrocarbonproduction is represented the inormation can be taken to approximate industry perormance. In Arica,

Asia/Australasia and South America, the data give a broad indication o industry perormance. For theMiddle East and North America, the regional coverage is less comprehensive, giving a weaker indicationo industry perormance. For the Former Soviet Union (FSU), data reported by participating companiesrepresent just 9% o the total sales production or that region. Data or this region are thereore onlyrepresentative o the perormance o those companies reporting and not o the industry as a whole.

Te number o companies reporting has fluctuated between years. Data are presented on a normalised basisto help control or this effect. Nevertheless, normalised perormance indicator results may be influenced bychanges in the list o reporting companies as well as changes in mixtures o assets held by the participatingcompanies between years. Differences between years or participating companies may also, in some cases,reflect changes in calculation methodology applied or reporting definitions. Tus, though the coverage oE&P activities is good, changes in results may not necessarily reflect actual changes in perormance.

Normalised analyses are only possible when data are available or both the metric to be normalised(emissions, discharges, spills) and the normaliser (hydrocarbon production, produced water). Some o theanalyses will cover less than 100% o the total production reported because some companies did not submitdata or all metrics covered in the survey. Coverage or the analyses is presented below.

Percentage of reported production included in normalised analyses

AfricaAsia/

Australasia Europe FSUMiddle

EastNorth

AmericaSouth

America All regions

Gas emissions

CO2

96% 99% 100% 100% 90% 100% 100% 97%

CH4

96% 86% 100% 97% 90% 100% 100% 95%

NMVOC 92% 77% 99% 96% 84% 100% 99% 92%

SO2

95% 78% 100% 100% 90% 100% 100% 94%

NOX

95% 79% 100% 100% 90% 100% 100% 94%

Energy consumed 89% 98% 98% 97% 57% 99% 100% 89%

Flaring 99% 97% 98% 96% 100% 96% 99% 98%

Oil discharged in produced water 80% 95% 95% 77% 60% 84% 98% 84%

Oil spills 100% 87% 95% 95% 74% 92% 95% 90%

In 2009, data on the source types o gaseous emissions (e.g. energy, flare, vent, ugitive emissions, andother) were collected or the first time. It was recognised that not all participating companies would beable to contribute data at that level o detail in the beginning; nevertheless, data broken down by source

cover roughly hal o the gaseous emissions reported or 2009, 2010 and 2011. It is expected that thisinormation will be helpul in understanding some o the trends in the data as well as to help indicate areasor improvement. Data coverage or the breakdown is expected to improve over time.

Te current year data shown in this report are based on best available inormation provided by membercompanies at time o publication. Data or previous years shown in this report are normally based on data

published in previous years reports. However, in some cases, corrections provided by member companies havebeen made to data or previous years when these corrections significantly impact regional or global results.


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OGP

Releases o gases to the atmosphere are an integral and inevitable part o exploration, production andprocessing operations. Te principal (routine) sources are flaring, venting, turbine and engine operation,fluids processing and ugitive losses (or example rom pumps, gas driven valves, flanges and pipes). Non-

routine and emergency emissions can arise rom well testing, emergency flaring and gas venting.

Gaseous emissions covered in this report are those considered most relevant rom process control as wellas regulatory perspectives. Tey are: carbon dioxide (CO

2), methane (CH

4), non-methane volatile organic

compounds (NMVOC), sulphur dioxide (SO2) and nitrogen oxides (NO

X), and separately, greenhouse

gases (CO2+ CH

4expressed as CO

2equivalent).

Given the wide range o sources o gaseous emissions, it is not practicable (or possible) to measure everysingle release individually. Industry has, however, developed and updated detailed guidance methodologiesto calculate and estimate emissions and losses. Since companies may use a variety o estimation techniquescare must be taken when interpreting aggregated data.

A number o actors affect the quantity o gases emitted rom E&P petroleum industry operations.

Consequently, understanding the variations in perormance in terms o normalised emission ratios iscomplex. Tese actors include:

presence or absence o inrastructure or gas sales

gas-oil ratio

reservoir and field characteristics

use o hydrocarbon recovery techniques

regulatory and contractual aspects

location and logistics

age o the fields

Te ollowing sub-sections present the overall emission data or the years 2005 to 2011 and regional emissiondata or 2009 to 2011.

In 2011, participating OGP member companies reported emissions o: 289 million tonnes o carbon dioxide (CO

2) equivalent to 133 tonnes o carbon dioxide per thousand

tonnes o hydrocarbon production;

2.6 million tonnes o methane (CH4) equivalent to 1.2 tonnes o methane per thousand tonnes o

hydrocarbon production;

1.0 million tonnes o non-methane volatile organic compounds (NMVOC) equivalent to 0.5 tonneo NMVOC per thousand tonnes o hydrocarbon production;

364 thousand tonnes o sulphur dioxide (SO2) equivalent to 0.2 tonne o SO


hydrocarbon production; and

864 thousand tonnes o nitrogen oxides (NOX) equivalent to 0.4 tonne o NOXper thousand tonneso hydrocarbon production.

Detailed review: Gaseous emissions

ee or example:etroleum ndustry uidelines or Reporting reenhouse as missions (2003)oint PIECA/PI/GP report, 2003 (in revision);ompendium o reenhouse as mission stimation ethodologies or the il and as ndustry, PI, 2009;


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OGP

Normalised figures or 2011 emissions (see Figure 1) are broadly consistent with data published or activitiesin 2005-2010.

Figure 1 Emissions per thousand tonnes hydrocarbon production tonnes per thousand tonnes

0.0

0.2

0.4

0.6

0.8

1.0

1.2

2011

2010

2009

2008

2007

2006

2005

NOX

SO2

NMVOCCH4

1.3

0.5

0.2

0.4

0

50

100

150

200

GHGCO2

133

159

GHG: Total GreenHouse Gases (CO2+ CH4expressed as CO2equivalent)

ote: s 2

contributes only to a small faction to greenhouse gas emissions fom & activities, it has not been included here.


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OGP

. Carbon Dioxide (CO)

Emissions o carbon dioxide occur principally rom the flaring and combustion o uels or energy production

and are thereore a unction o the type and quantity o uel burned. Carbon dioxide releases may also occurwhere CO

2is used or enhanced petroleum recovery or where it is stripped rom the natural reservoir gases

to meet sales specifications.

.. missions per unit of production

Global CO2 emissions normalised to

hydrocarbon production or 2011 were133 tonnes o CO


production, as shown in Figure 1.1.1a.

Regional averages or quantity o carbondioxide emissions per unit o production

vary rom 47 to 215 tonnes o carbon dioxideper thousand tonnes o hydrocarbonproduction, as shown in Figure 1.1.1b. In2010 the range was between 52 and 206tonnes per thousand tonnes o production.

.. missions by source

Te source was specified or 54% o the reportedcarbon dioxide emissions.

Where the source is specified, 59% o the reportedcarbon dioxide emissions are rom energy use, 36%are rom flaring and 5% are attributable to venting, asshown in Figure 1.1.2. In 2010, 58% o the reported

carbon dioxide emissions were rom energy use, 38%were rom flaring and 4% were rom venting.

0

30

60

90

120

150

2011201020092008200720062005

132

142 142 142

135133 133

Figure 1.1.1a: CO2emissions per unit of production tonnes per thousand tonnes of hydrocarbon production

Vents 5%

Flare 36%

Energy 59%

Figure 1.1.2: CO2emissions by source

Note: excludes emissions where the source is not specified

0

50

100

150

200

250

300 2011

2010

2009

SouthAmerica

NorthAmerica


Africa

215

184

47

75

181

100

136

Overall 133

Figure 1.1.1b: CO2emissions per unit of production tonnes per thousand tonnes of hydrocarbon production


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OGP

. Methane (CH)

Methane is emitted rom sources including

process vents, gas-driven pneumatic devicesand tank vents. It also escapes as ugitiveemissions rom process components (valves,flanges, etc.) that carry process streamscontaining significant quantities o methane.In addition, some methane emissions resultrom incomplete combustion o hydrocarbonsin turbines, engines and flare equipment.

.. missions by unit of production

Normalised CH4 emissions show a 6%

increase compared with 2010, as indicatedin Figure 1.2.1a

Regional averages or methaneemissions expressed per unito production vary rom 0.2to 2.8 tonnes o methane perthousand tonnes o hydrocarbon

production, as shown inFigure 1.2.1b. In 2010 therange was between 0.2 and 2.5tonnes per thousand tonnes o

production.

Emissions intensity or Europeand the Middle East is lower thanor other regions. In Europe this is

partly due to low levels o flaringand venting in the region as well asto stringent regulatory controlsthat limit ugitive emissions. Inthe other regions there are higherrates o natural gas flaring and

venting in certain types o

production acilities.


Te source was specified or 54% o the totalmethane emissions reported.

Where the source is specified, the largestportion o methane emissions, 32%, is romvents (including venting, vessel loading, tankstorage, etc.); 27% is rom flaring, 27% isrom ugitive losses and 14% is rom energyuse, as shown in Figure 1.2.2. In 2010, 41%o the reported methane emissions wererom venting, 26% were rom flaring, 20%

were attributable to ugitive losses and 13%were rom energy use.

0.0

0.2

0.4

0.6

0.8

1.0

1.2

1.4

2011201020092008200720062005

1.18

1.25

1.11

1.001.04

1.02

1.14

Figure 1.2.1a: CH4emissions per unit of production

tonnes per thousand tonnes of hydrocarbon production

0.0

0.5

1.0

1.5

2.0

2.5

3.0 20112010

2009

SouthAmerica

NorthAmerica


Africa

2.

8

0.

4

0.6

0.

2

2.

2

1.

5

1.

2

Overall 1.3

Figure 1.2.1b: CH4emissions per unit of production tonnes per thousand tonnes of hydrocarbon production

Vents 32%

Fugitivelosses 27%

Flare 27%

Energy14%

Figure 1.2.2: CH4emissions by source

Note: excludes emissions where the source is not specified


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OGP

. Greenhouse Gas (GHG)

For E&P activities, CO2 and CH

4 are the

principal contributors to greenhouse gasemissions, with other gases such as N

2O

playing a minor role. Te CO2 and CH

4

data presented above are used to calculatean estimate o the GHG emissions or thecontributing OGP reporting companies,using the standard conversion to CO

2

equivalent (GHG = CO2+ 21 x CH

4).


Based on reported data, the average o

159 tonnes o GHG per thousand tonneso hydrocarbon production is almostunchanged compared with that seen in

previous years (see Figure 1.3.1a)

Regional averages or quantityo greenhouse gas emissions

per unit o production varyrom 51 to 247 tonnes tonneso greenhouse gas per thousandtonnes o hydrocarbon

production, as shown in

Figure 1.3.1b. In 2010 therange was between 55 and 238tonnes per thousand tonnes o

production.


Te source was specified or 54% o the totalreported greenhouse gas emissions.

Where the source is specified, 51% o thereported greenhouse gas emissions are romenergy use, 35% are rom flaring, 10% arerom venting or vents and 4% are attributableto ugitive losses, as shown in Figure 1.3.2.In 2010, 51% o the reported greenhouse gas

emissions were rom energy use, 36% wererom flaring, 10% were rom venting and 3%were attributable to ugitive losses.

HG: otal reenhouse ases (O2+ H

4expressed as O

2equivalent)

0

30

60

90

120

150

180

2011201020092008200720062005

162156

164163

159 159158

Figure 1.3.1a: GHG emissions per unit of production


0

50

100

150

200

250

300 2011

2010

2009

SouthAmerica

NorthAmerica

MiddleEast

FSUEuropeAsia/Australasia

Africa

247

243

84

51

227

162

112

Overall 159

Figure 1.3.1b: GHGemissions per unit of production tonnes per thousand tonnes of hydrocarbon production

Vents10%

Fugitive losses 4%

Flare 35%

Energy 51%

Figure 1.3.2: GHG emissions by sourceNote: excludes emissions where the source is not specified


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OGP

. Non-Methane Volatile Organic Compounds (NMVOCs)

NMVOC emissions mainly occur rom

non-combustion sources such as ventingand ugitive releases (including crudeoil loading). In addition, NMVOCs areemitted in the exhaust o combustionequipment and are, thereore, a unction othe nature and quantity o uel burnt, thetype o combustion device used and themode o operation.

.. missions per unit of productionNormalised NMVOC emissions

were 0.50 tonnes per thousand tonneso hydrocarbon, virtuallyunchanged compared to 2010.See Figure 1.4.1a.

Regional averages or quantityo NMVOC emitted per unito production vary rom 0.18 to0.86 tonnes per thousand tonnes

o hydrocarbon production, asshown in Figure 1.4.1b. In 2010the range was between 0.06 and0.81 tonnes per thousand tonneso production.


Te source was specified or42% o the total NMVOC emissionsreported.

Where the source is specified, 46% oNMVOC emissions come rom ventingor vents, 32% rom flaring, 18% romugitive losses and 4% rom energy use, asshown in Figure 1.4.2. In 2010, 45% o thereported NMVOC emissions were rom

flaring, 37% were rom venting, 13% wereattributable to ugituve losses and 5% wererom energy use.

0.0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

2011201020092008200720062005

0.50 0.50

0.79

0.700.68

0.58

0.53

Figure 1.4.1a: NMVOC emissions per unit of production tonnes per thousand tonnes of hydrocarbon production

0.0

0.2

0.4

0.6

0.8

1.0

1.2 2011

2010

2009

SouthAmerica

NorthAmerica


Africa

0.8

6

0.2

2

0.1

8 0.2

5

0.6

20.7

2

0.6

1

Overall 0.50

Figure 1.4.1b: NMVOC emissions per unit of production tonnes per thousand tonnes of hydrocarbon production

Vents 46%

Fugitivelosses 18%

Flare 32%

Energy 4%

Figure 1.4.2: NMVOC emissions by sourceNote: excludes emissions where the source is not specified


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OGP

. Sulphur dioxide (SO)

Sulphur dioxide emissions by the E&P

industry arise through oxidation duringcombustion o sulphur naturally contained

within hydrocarbon uels or flared gas. Terate o emission thereore is principallya reflection o the sulphur content o

produced hydrocarbons, which varies widelydepending on the nature o the hydrocarbon

produced. Flaring o gases rom the sulphurremoval process represents one o the biggestsources o SO

2, together with flaring o

associated gas containing H2S.


Normalised SO2 emissions were 0.17

tonnes per thousand tonnes o hydrocarbonproduction, virtually unchangedcompared with 2010 results. SeeFigure 1.5.1a.

Regional averages or quantity oSO

2emissions expressed per unit

o production vary rom 0.03 to0.54 tonne per thousand tonnes

o hydrocarbon production, asshown in Figure 1.5.1b. In 2010the range was between 0.04 and0.57 tonne per thousand tonneso production.


Te source was reported or 50% o thetotal SO

2emissions.

Where the source is specified, the largestpercentage o sulphur dioxide emissions,63%, relate to flaring. 28% were rom energyuse, 7% were rom venting or vents and theremaining 2% were rom ugitive losses, asshown in Figure 1.5.2. In 2010, 67% o thereported sulphur dioxide emissions were

rom flaring, 30% were rom energy use and3% were rom venting.

0.00

0.05

0.10

0.15

0.20

0.25

2011201020092008200720062005

0.17 0.17

0.20 0.20

0.18 0.18 0.18

Figure 1.5.1a: SO2emissions per unit of production tonnes per thousand tonnes of hydrocarbon production

0.0

0.1

0.2

0.3

0.4

0.5

0.6 2011

2010

2009

SouthAmerica

NorthAmerica


Africa

0.

04

0.

24

0.

19

0.

03

0.

54

0.

10

0.

08

Overall 0.17

Figure 1.5.1b: SO2emissions per unit of production


Vents7%

Fugitivelosses 2%

Flare 63%

Energy 28%

Figure 1.5.2: SO2emissions by sourceNote: excludes emissions where the source is not specified


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OGP

. Nitrogen oxides (NOX)

Emissions o nitrogen oxides, (principally

nitric oxide and nitrogen dioxide,expressed as NO

X), occur almost

exclusively rom the combustion onatural gas or other uels. Tese emissionsare a unction o the combustion peaktemperature, and thereore o the typeand operation o combustion device.NO

Xemissions are requently estimated

rather than measured and consequentlythey are strongly dependent upon thecalculation methodology.

.. missions per unit ofproduction

Global NOX

emissionsnormalised to hydrocarbon

production or 2011 were 0.41tonnes per thousand tonnes o

production, approximately 3%higher than the 2010 results(see Figure 1.6.1a). NormalisedNO

Xemissions are highest in the

North America region, with anaverage o 0.77 tonne o NOX

perthousand tonnes o hydrocarbon

production, reflecting the highenergy intensity. Te Middle Eastregion has the lowest normalisedNO

X emissions o 0.15 tonne

NOX

per thousand tonnes ohydrocarbon production, asshown in Figure 1.6.1b. In 2010the range was between 0.15and 0.69 tonne per thousand tonnes o

production.


Te source was reported or 48% o thetotal nitrogen oxide emissions reported.

Where the source is specified, 93% onitrogen oxide emissions are rom energyuse. Te remaining 7% are rom flaring,as shown in Figure 1.6.2. In 2010, 92%o the reported NO

Xemissions were rom

energy use and 8% were rom flaring.

0.0

0.1

0.2

0.3

0.4

0.5

2011201020092008200720062005

0.40

0.32

0.38

0.41 0.41 0.41

0.39

Figure 1.6.1a: NOXemissions per unit of production tonnes per thousand tonnes of hydrocarbon production

0.0

0.1

0.2

0.3

0.4

0.50.6

0.7

0.8

0.92011

2010

2009

SouthAmerica

NorthAmerica

MiddleEast


Africa

0.4

0

0.4

7

0.2

8

0.2

4

0.1

5

0.7

7

0.7

1

Overall 0.41

Figure 1.6.1b: NOXemissions per unit of production tonnes per thousand tonnes of hydrocarbon production

Flare7%

Energy 93%

Figure 1.6.2: NOXemissions by sourceNote: excludes emissions where the source is not specified


21/6215


OGP

Energy consumption

Te energy used to produce oil and gas covers a range o activities. Tese include: driving pumps that produce the hydrocarbons (and any associated produced water);

heating produced oil or separation;

producing steam or enhanced oil recovery;

driving the pumps to re-inject produced water, inject water or water-flooding and transport theproduced oil through pipelines;

powering compressors to re-inject produced gas or to export it through pipelines; and

driving turbines to generate electricity needed or operational activities, including logistics, and orliving quarters (egat offshore platorms).

Energy consumption will vary widely depending upon the specific local circumstances and operationalconditions. For example, mature or remote fields usually consume more energy than other fields.

In 2011, OGP reporting companies consumed on average 1.6 GigaJoules o energy or every tonne o

hydrocarbon produced, as shown in Figure 2.1. Tis is an increase o 7% compared with the 2010 average.As in previous years, data indicate that onshore production in 2011 was more energy intensive than offshore

production.

Te majority o energy requirements were met by combustion o uels on-site rather than by purchase oelectricity or steam. No breakdown was specified or 15% o the total; where a breakdown was provided,95% was derived rom on-site combustion and 5% was purchased.

Figure 2.1: Energy consumed per unit of hydrocarbon production GigaJoules per tonne

0.0

0.3

0.6

0.9

1.2

1.5

1.8Unspecified energy Purchased energy On-site combustion

2011201020092008200720062005200420032002


22/6216


OGP

In Figure 2.2, the (overall) energy consumption is normalised against the quantity o hydrocarbons producedor each region. Tis analysis shows that operations in North America were the most energy intensive (3.06GigaJoules per tonne o hydrocarbon produced), while the Middle East was the least energy intensive (0.78

GigaJoules per tonne)

Figure 2.2: Energy consumption per unit of hydrocarbon production by region GigaJoules per tonne

0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.52011

2010

2009

SouthAmerica

NorthAmerica


Africa

1.3

3

1.

72

1.1

4

1.1

1

0.7

8

3.0

6

1.

69

Overall 1.57


23/6217


OGP

Flaring is the controlled burning o hydrocarbons produced in the course o petroleum exploration andproduction operations. It includes the controlled and sae burning o gas that, or commercial, saety ortechnical reasons, is not used or exported.

In 2011, 15.7 tonnes o gas were flared or every thousand tonnes o hydrocarbon produced versus 16.0 in2010 and 17.6 in 2009, as shown in Figure 3.1.

Figure 3.1: Flaring per unit of hydrocarbon production Tonnes per thousand tonnes

0

5

10

15

20

25

201120102009200820072006

23.9

20.4

18.817.6

16.0 15.7

Figure 3.2 shows the flaring per unit o hydrocarbon production as reported by the participating companiesby region.

Figure 3.2: Flaring per unit of hydrocarbon production by region Tonnes per thousand tonnes

0

10

20

30

40

50

60 2011

2010

2009

SouthAmerica

NorthAmerica

MiddleEast


Africa

50.7

17.6

3.6

6.4

3.4 1

1.

3

11.7

Overall 15.7

NB: represents either hydrocarbon only or total flare figures as reported by companies. In most cases these two metrics are similar in magnitude.

Intensities are higher in the Arica region where there is limited gas sales inrastructure. Projects in Aricathat are increasing the capability to inject gas or reservoir maintenance and to deliver gas to markets havehelped reduce flaring rom 60.2 tonnes o gas flared or every thousand tonnes o hydrocarbon producedin 2008 to 50.7 in 2011. Tis reduction is reflected in the overall average as the total hydrocarbon flared inArica is more than three times the average or all regions.

Flaring


24/6218


OGP


25/6219


OGP

Produced water is the highest volume liquid discharge generated during the production o oil and gas. Itconsists o ormation water (water present naturally in the reservoir), floodwater (water previously injectedinto the reservoir) and/or condensed water (in the case o some gas production).

Afer extraction, produced water is separated and treated (de-oiled) beore discharge to surace water(including seas, rivers, lakes, etc.) or to land (including to evaporation ponds). Produced water can also beinjected either into the producing reservoir where it can enhance hydrocarbon recovery or into anotherappropriate ormation or disposal. Te volume o produced water typically increases as oil and gas fields age.As context, the worldwide volume o produced water reported in this database in 2011 was approximately1.5 times that o hydrocarbon production.

Discharge o produced water is regulated in most countries. Regulations usually vary between onshore andoffshore, and rom one country to another. Differences in onshore and offshore regulations reflect differingenvironmental conditions and sensitivities. For example, salt content and biochemical oxygen demand (BOD)can be important aspects where discharges are to rivers or where these may have an impact on potable aquiers.

Tese actors are less important or offshore discharges where the ocus is more on the oil content o producedwater. Te quality o produced water is most widely expressed in terms o its oil content. Tere are a numbero analytical methodologies in use around the world or measuring oil in water. As a result o differences inanalytical methodologies, care should be taken when interpreting aggregated data.

ote: Offshorereers to operations that take place at sea, including inland seas directly connectingto oceans. perations in bays, in major inland seas, e.g. the aspian ea, or in other inland seasdirectly connected to oceans are counted as offshore. Onshorereers to operations that take placewithin a landmass, including those on swamps, rivers and lakese e.g. emissions, discharges andenergy fom crude oil and natural gas terminals are categorised by the source o production and notthe location where they occur, i.e. where production is offshore and emissions and/or discharges are

generated fom an onshore terminal, the emissions and/or discharges are reported as offshore.

Aqueous discharge covers the discharge o produced water, mainly produced ormation water.

In 2011, where the location was specified, approximately 88% o water discharged was rom offshoreoperations and 12% was rom onshore operations.

For every tonne o hydrocarbon produced in 2011, 0.5 tonne o produced water was discharged to thesurace and 1.0 tonne o produced water was re-injected. Similarly in 2010, 0.5 tonne o produced water

was discharged to the surace and 1.0 tonne was reinjected.

Te overall average oil content in produced water discharges was 12mg/l, compared with 13mg/l in2010 and 13mg/l in 2009. Offshore the average oil content in produced water was 12mg/l, whilstonshore it was 8mg/l (see Figure 4.1a)

Aqueous Discharges


26/6220


OGP

. Quality (oil content) of produced water discharges

Figure 4.1a Oil discharged per unit of produced water discharged milligrammes oil per litre of produced water discharged

0

5

10

15

20

252011 2010 2009 2008

2007 2006 2005

OverallOnshoreOffshore

8

12 12

Regional averages or the oil content o produced water discharged vary offshore rom 10.3 to 16.4mg/l(Figure 4.1.b) while onshore they vary rom 0.3 to 29.7mg/l (Figure 4.1.c).

Figure 4.1b: Oil content of produced water discharged offshore milligrammes oil per litre of produced water discharged (equivalent to tonnes per million tonnes)

0

5

10

15

20

25

302011

20102009

SouthAmerica

NorthAmerica

MiddleEast


Africa

12.

3

11.0

Overall 12.2 11.7

10.3

13.

0

0.0

16.

4

FSU quantity produced water offshore is very low (0.05 million tonnes). See Scope of data submissions and Section 4 of Appendix A.


27/6221


OGP

Figure 4.1c: Oil content of produced water discharged onshore milligrammes oil per litre of produced water discharged (equivalent to tonnes per million tonnes)

0

5

10

15

20

25

302011

2010

2009

SouthAmerica

NorthAmerica


Africa

3.2

5.

5

2.1

0.3

35

29

.7

38

64

80

1.7

Overall 8.1

10

8

Te regional variations shown in this section, and particularly in Figure 4.1.c, reflect changes in the numbero companies reporting oil discharges in produced water in 2011.

. Quantity of oil discharged in produced water per unit of production

Figure 4.2a: Oil discharged per unit of production tonnes per million tonnes of hydrocarbon production

0

3

6

9

12

152011 2010 2009 2008

2007 2006 2005


2

9

6


28/6222


OGP

Regional averages or the quantity o oil discharged by unit o production o hydrocarbons vary, onshore(see Figure 4.2c), rom a ew kg per million tonnes to 6.3t/106t in Arica, while offshore (Figure 4.2b) they

vary rom 0.0t/106t in the FSU to 13.5t/106t in Asia/Australasia.

As noted above, the difference between the overall averages onshore and offshore reflects the act thatproduced water is largely reinjected onshore (where environmental sensitivities to produced water especially salt are generally high) while the offshore environment is generally less sensitive to produced

water discharges.

Figure 4.2b: Oil discharged per unit of production offshore tonnes per million tonnes of hydrocarbon production

0

5

10

15

20

25

302011

2010

2009

SouthAmerica

NorthAmerica


Africa

13.

5

Overall 8.8

8.2

9.7

6.5

0.0 0

.7

11.8

Figure 4.2c: Oil discharged per unit of production onshore tonnes per million tonnes of hydrocarbon production

0

5

10

15

20

25

302011

2010

2009

SouthAmerica

NorthAmerica


Africa

0.

5

5.

8

6.

3

0.

0

0.

1

0.

0

2.

8

Overall 2.4


29/6223


OGP

. Produced Water Injection

Figure 4.3a: Percentage of produced water re-injected offshore by region expressed as percent total produced water generated offshore

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%2011

2010

2009

2008

2007

2006

2005


As stated previously, produced water is ofen injected back into reservoirs (reinjection) to improvehydrocarbon recovery or into other geological strata or disposal.

Offshore (Figure 4.3b), where de-oiled produced water can be discharged to sea with limited impact inthe majority o locations, there is much less reinjection (19% in 2011). Exceptions to this are locations

where injection would be beneficial to the management o the reservoir or where environmental sensitivityis considered to be high. In Europe 29% o the offshore produced water was reinjected while in North

America no produced water was reinjected.

Onshore, where disposal to surace is ofen constrained by regulatory and environmental concerns,injection o produced water is the principal disposal route with 90% o water being returned below ground(see Figure 4.3c).

Over the 3 years shown there is a slight increase in the quantity o water re-injected compared to waterdischarged both onshore and offshore.

Figure 4.3b: Percentage of produced water re-injected offshore by region expressed as percent total produced water generated offshore

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

OverallSouth

America

North

America

Middle EastFSUEuropeAsia/

Australasia

Africa

2009

2010

2011


30/6224


OGP

Figure 4.3c: Percentage of produced water re-injected onshore by region expressed as percent total produced water generated onshore

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

OverallSouthAmerica

NorthAmerica


Africa

2008 2009 2010


31/6225


OGP

While most drilling in the offshore oil and gas industry is achieved using water-based drilling fluids (muds),technical challenges ofen require the use o non-aqueous drilling fluids (NADF) that provide higherlubricity, stability at higher temperatures and well-bore stability compared with water-based muds. Tese

challenges arise especially with techniques such as extended-reach and directional drilling, both o whichmay be required to develop new reservoirs or to improve recovery rom previously identified resources. OGPreports non-aqueous base fluids (NABFs) according to the ollowing classifications:

Classification Base fluid Aromatic (%) PAH (%)

Group I Diesel and conventional mineral oil >5.0 >0.35

Group II Low toxicity mineral oil 0.5 5.0 0.001 0.35

Group I II Enhanced mineral oilSynthetics (esters, olefins, paraffins)


32/6226


OGP

Figure 5.1: Total base fluid (NABF) discharges to sea, by region; 20092011 tonnes

4000

0

8000

12000

16000

20000

24000

South AmericaNorth AmericaMiddle EastFSUEuropeAsia/AustralasiaAfrica

1,

169

8

42

2 0 0 012

8

508

487

4,

436

2,4

19

2,7

78

3,

035

2,4

07

1,

230

1,7

18

4

3,0

40

12

,203

20

,369

23

,87

6

Unspecified

2009 2010 2011

Group III

Group II

Note: NABF discharges were only reported by 19 companies in 2011; no Group 1 NABF discharges were r eported in 2009-2011


33/6227


OGP

Spills are an important environmental perormance indicator or the oil & gas industry since they can have asignificant and visible impact on the environment. Te degree o environmental impact is highly dependenton the nature o the release, where it occurred and how it was subsequently managed. Oil exploration and

production companies have spill contingency plans and measures in place to respond to and mitigate spills.

For the purpose o this report a spill is defined as any loss o containment that reaches the environment (i.e.is not retained within secondary or other confinement), irrespective o quantity recovered.

Spills may have a number o causes such as equipment ailure (including corrosion), operating errors,sabotage and thef.

Te majority o spills reported by OGP member companies are oil spills, which include spills o crude,condensate and processed oil. Chemical spills with release to the external environment occur onlyinrequently and quantities released are generally small. Relatively ew reports o chemical spills have beenreceived and the data or these are presented in Appendix A.

. Oil Spills

In 2011, companies reported a total o 6,996 spills. O these, 3,961 (57%) were spills o less than one barrelin volume, amounting to a total o 57 tonnes o oil. Because o the small cumulative volume involved and,as some companies do not report spills less than 1 bbl in size, these 1 bbl per unit of hydrocarbon production spills per million tonnes

0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0 2011

2010

2009

2008

2007

2006

2005

OverallOffshoreOnshore

3.5

0.2

1.5

Spills

Te eepwater orizon incident was not included in the 2010 report or this report. Te ulti-istrict litigationbeginning in 2012 will address the amount o oil spilled.


34/6228


OGP

Figure 6.2 shows the number o spills normalised per unit hydrocarbon production by region. Rates or2011 vary rom 0.1 spills per million tonnes o production in the FSU to 9.0 spills per million tonnes o

production in South America.

Figure 6.2: Number of oil spills > 1 bbl per unit of hydrocarbon production by region spills per million tonnes

0

2

4

6

8

102011

2010

2009

SouthAmerica

NorthAmerica


Africa

0.2 0

.4

0.1 0

.4

9.0

1.7

1.4

Overall 1.5

With regard to oil spill volumes, the 3,035 oil spills greater than 1 bbl in size reported or 2011 resulted inthe release o a total o 15,867 tonnes o oil.

When normalised to hydrocarbon production (see Figure 6.3), spill volume rates do not show any consistenttrend over the 7-year period shown. Te normalised spill volume rate reported or offshore operations was

less than hal o the onshore rate.Figure 6.3: Quantity of oil spilled per unit of hydrocarbon production tonnes per million tonnes

0

5

10

15

20

OverallOffshoreOnshore

47.0

5

12

8

The Deepwater Horizon incident was not included in the 2010 report or this report.The Multi-District litigation beginning in 2012 will address the amount of oil spilled.

2007

2006

2005

2011

2010

2009

2008


35/6229


OGP

Te quantity o oil spil led per unit o hydrocarbon production by region is shown in Figure 6.4.

Figure 6.4: Quantity of oil spilled (spills > 1 bbl) per unit of hydrocarbon production by region

tonnes per million tonnes

0

10

20

30

40

50

602011

2010

2009

SouthAmerica

NorthAmerica


Africa

1.1

0.

1

10.3

10.4

4.

0

23.

8

0.5

Overall 7.9

Figures 6.5 and 6.6 show the reported quantities o oil spilled per unit o hydrocarbon production, onshoreand offshore respectively, in the different geographic regions.

Figure 6.5: Quantity of oil spilled (spills > 1 bbl) per unit of hydrocarbon production onshore by region tonnes per million tonnes

0

20

40

60

80

1002011

2010

2009

SouthAmerica

NorthAmerica


Africa

0.4

0.2

31.7

5.3

305

7.6

26.1

12.3

Overall 12.1


36/6230


OGP

Figure 6.6: Quantity of oil spilled (spills > 1 bbl) per unit of hydrocarbon production offshore by region tonnes per million tonnes

0

5

10

15

20

252011

2010

2009

SouthAmerica

NorthAmerica


Africa

23.

6

0.

50.

8

0.

0

0.

0

0.

0

2.

4

Overall 5.2

Te increase in 2011 in the quantity o oil spilled offshore per unit o production in Arica, as shown inFigure 6.6, is the result o a single oil spill in Nigeria in which 4.8 thousand tonnes o oil were spilled duringthe transer o oil rom a floating production, storage and offloading vessel to an oil tanker, 120km offshore.

Figure 6.7: Distribution of oil spills onshore and offshore by size number of spills

0

500

1000

1500

2000

2500 Unspecified

Offshore

Onshore

Unspecified> 100 bbl10 < x < 100 bbl1 < x < 10 bbl

num

bero

fspills

18427 20 0172076338

2,280

154225

Figure 6.7 shows the distribution o spills larger than 1 barrel in terms o number o spills in each sizecategory. In terms o number o events, the distribution is dominated by the number o spills between 1 and10 barrels in size. However, the quantity released overall (or those spills where a size category was specified)is dominated by a ew relatively large events.

In addition to the data shown in Figure 6.7, a total o 3,961 spills (2,796 onshore, 918 offshore, and 247unspecified location) o less than 1 barrel in size were reported by participating companies.


37/6231


OGP

pills greater than barrels in size

Tere were 90 reported spills in which more than 100 barrels o oil was released (63 onshore, 7 offshore, 20

unspecified location).Te cause was reported or 37 o these cases which collectively were associated with 61% o the total oilspilled. 21 o those incidents (9% o the total oil spilled) were caused by equipment ailure (excludingcorrosion). A urther 5 o the oil spills (4% o the total oil spilled) were caused by corrosion and 4 (17% othe total oil spilled) by operator or technical error. 2 o the incidents (1% o the total oil spil led) were causedby third party damage (sabotage, thef, vandalism, etc).

O the 5 incidents categorised as other or unknown (30.8% o the total oil spilled), 1 (29.9%) occurredduring the offshore transer o oil rom an FPSO to a tanker in Nigeria, 2 (0.6%) were caused by sea bedseepage, 1 (0.3%) by a ailure in equipment design specification, and 1 (0.1%) by equipment damageresulting rom a tank explosion.

Figure 6.8 shows spill incidents greater than 100 barrels in size by cause as a percentage o the total numbero spill incidents >100 bbl in size where the cause was reported.

For the first time in 2010 detailed inormation has been reported or spills between 10 and 100 barrels insize. 265 spills in this category were reported in total and inormation on causes was provided or 150 othose incidents (See Figure 6.9).

Unknown3%

Other11%

Third party damage(sabotage, theft, valdalism, etc.)5%

Operator ortechnical error

11%Equipment failure

(excluding corrosion)57%

Corrosion13%

Figure 6.8: Spills >100bbl in size by cause as % of spill incidents

Third party damage

(sabotage, theft, valdalism, etc.) 8%Other8%

Operator ortechnical error

12%

Equipment failure(excluding corrosion)

48%

Corrosion24%

Figure 6.9: Spills 10-100bbl in size by cause as % of spill incidents where cause was indicated

pills between and barrels in size

Since 2010, detailed inormation has been reported or spills between 10 and 100 barrels in size. In 2011,249 spills in this category were reported in total and inormation on causes was provided or 120 o thoseincidents (See Figure 6.9).

In 2010, 265 spills between 10-100 bbl in size were reported and inormation on causes was provided or 150o those incidents. 22% o the incidents reported in 2010 were due to Equipment ailure, 15% to Equipmentailure excluding corrosion, 10% to Operator or technical error, 8% to Sabotage, 7% to echnical operatingerror, 3% to Tird party damage and 1% to echnical operating error ailure to ollow procedures. Teremaining 17% were categorised as other or unknown. Note the causal categories have been simplified or

2011 data.


38/6232


OGP


39/6233


OGP

Appendix A Data tables

Te ollowing tables provide the data rom which the figures and charts throughout the report are compiled.

Scope of data submissionsProduction associated with database and 2011 production in BP Statistical Review of World Energy by region

Region Production i n th is report (106t) BP Review production (106t) Production as % of BP Reviewproduction

Equivalent last year

Africa 387 600 64% 61%

Asia/Australasia 355 819 43% 46%

Europe 452 406 111% 107%

FSU 127 1,366 9% 9%

Middle East 411 1,775 23% 22%

North America 295 1,454 20% 23%

South America 194 531 37% 41%

Total 2,221 6,950 32% 33%

NB: Production figures given in this report relate to gross production whereas world data extracted from the BP Statistical Review represent net production. Thus the data arenot directly comparable, but the percentage of world production figures are given as indicative of the relative regional contributions in the database.

No. of useable company/country data sheets/sets by region

2011 2010 2009

Region No. of data sheets No. of data sets No. of data sheets No. of data sets No. of data sheets No. of data sets

Africa 57 80 49 61 50 65

Asia/Australasia 54 70 55 68 52 74

Europe 60 77 51 68 56 77FSU 13 14 10 11 12 14

Middle East 21 26 18 27 17 24

North America 21 30 21 33 23 35

South America 28 36 24 31 27 43

Total 254 333 228 299 237 332

Data sheet: all data for one country for an individual companyData set: a set of data with distinct company, country and location (onshore/offshore/unspecified) where there is a positive return of production, emission s, discharges, energy or spill

data


40/6234


OGP

Detailed review

Gaseous emissions

Gas emissions per unit of hydrocarbon production (Figures 1.1a, 1.2.1a, 1.3.1a, 1.4.1a, 1.5.1a, 1.6.1a)

2011 2010 2009

Emission per 103tproduction (t/103t)

Hydrocarbonproduction 106t





CO2

133.23 2,161 133.39 2,226 135.22 2,151

CH4

1.25 2,111 1.18 2,176 1.14 2,116

NMVOC 0.50 2,034 0.50 2,087 0.53 2,036

SO2

0.17 2,080 0.17 2,108 0.18 2,058

NOX 0.41 2,084 0.40 2,113 0.39 2,061GHG 159.39 158.08 159.19

GHG: Total greenhouse gases (CO2+ CH

4expressed in CO

2equivalent: GHG = CO

2+ 21 x CH

4)

NB Data only included where gas quantit y and production level are both reported

Gross emissions of gases per region

AfricaAsia/

Australasia Europe FSU Middle East North America South America Overall

2011

CO2(106t) 79.6 64.7 34.3 12.7 17.7 53.3 26.6 288.9

CH4(103t) 565.2 861.7 186.2 72.2 58.4 648.9 237.7 2,630.3

NMVOC (103

t) 305.3 196.7 99.2 21.5 87.7 180.4 120.4 1,011.1SO

2(103t) 31.6 9.5 16.4 30.4 199.2 57.0 20.4 364.5

NOX(103t) 151.0 130.9 129.0 30.6 55.6 228.6 138.5 864.2

GHG (106t) 91.5 82.8 38.2 14.2 19.0 67.0 31.6 344.1

2010

CO2(106t) 83.5 68.5 35.0 10.7 16.1 54.5 29.0 297.4

CH4(103t) 617.8 823.9 201.1 63.3 50.9 537.9 263.1 2,557.9

NMVOC (103t) 328.3 196.4 126.8 7.7 71.9 188.9 114.5 1,034.5

SO2(103t) 41.0 13.0 19.2 30.3 176.9 64.5 17.5 362.4

NOX(103t) 152.6 150.0 119.6 26.4 47.0 223.6 141.0 860.2

GHG (106t) 96.5 85.8 39.3 12.0 17.2 65.8 34.6 351.1

2009

CO2(106t) 81.3 62.0 34.7 11.2 18.1 51.6 32.4 291.3

CH4(103t) 521.0 778.2 131.8 80.5 45.5 543.8 316.6 2,417.4

NMVOC (103t) 365.8 168.7 123.4 15.5 72.5 195.7 130.5 1,072.0

SO2(103t) 43.7 9.9 15.7 26.9 185.9 68.1 19.9 370.1

NOX(103t) 162.6 116.6 121.9 27.1 28.2 226.8 134.0 817.3

GHG (106t) 92.2 78.3 37.5 12.9 19.1 63.0 39.1 342.1


4expressed in CO


2+ 21 x CH

4)


41/6235


OGP

Emissions per unit of hydrocarbon production (tonnes per thousand tonnes) by region (Figures 1.1b, 1.2.1b, 1.3.1b, 1.4.1b, 1.5.1b, 1.6.1b)

AfricaAsia/

Australasia Europe FSU Middle EastNorth

AmericaSouth

America Overa ll

2011

CO2emissions (t/103t) 214.71 183.53 74.95 99.95 47.48 180.57 136.11 133.23

Production (106t) 370 351 452 127 371 295 194 2,161

CH4emissions (t/103t) 1.53 2.81 0.41 0.59 0.16 2.20 1.22 1.25

Production (106t) 370 307 451 123 371 295 194 2,111

NMVOC emissions (t/103t) 0.86 0.72 0.22 0.18 0.25 0.61 0.62 0.50

Production (106t) 356 274 448 122 347 295 193 2,034

SO2emissions (t/103t) 0.08 0.03 0.04 0.24 0.54 0.19 0.10 0.17

Production (106t) 366 277 452 126 371 295 194 2,081

NOXemissions (t/103t) 0.40 0.47 0.28 0.24 0.15 0.77 0.71 0.41

Production (106

t) 366 280 452 126 371 295 194 2,084GHG emissions (t/103t) 246.84 242.54 83.56 112.34 50.84 226.77 161.73 159.40

2010

CO2emissions (t/103t) 205.98 177.24 73.67 88.78 51.76 165.88 143.51 133.39

Production (106t) 405 386 474 120 310 328 202 2,226

CH4emissions (t/103t) 1.53 2.45 0.42 0.53 0.16 1.64 1.30 1.18

Production (106t) 405 336 474 120 310 328 202 2,176


Production (106t) 404 279 474 120 287 322 202 2,087

SO2emissions (t/103t) 0.10 0.05 0.04 0.25 0.57 0.20 0.09 0.17

Production (106t) 404 276 474 120 310 322 201 2,108

NOXemissions (t/103t) 0.37 0.53 0.25 0.22 0.15 0.69 0.69 0.40

Production (106t) 404 281 474 120 310 322 202 2,113

GHG emissions (t/103t) 238.11 228.69 82.49 99.91 55.12 200.32 170.81 158.08

2009

CO2emissions (t/103t) 214.88 190.37 73.29 85.68 53.69 161.97 169.66 135.22

Production (106t) 378 325 473 131 335 318 191 2,151

CH4emissions (t/103t) 1.38 2.66 0.28 0.62 0.13 1.71 1.66 1.14

Production (106t) 378 292 473 129 335 318 191 2,116


Production (106t) 367 257 473 131 307 310 191 2,036

SO2emissions (t/103t) 0.12 0.04 0.03 0.21 0.56 0.22 0.10 0.18

Production (106t) 367 255 473 131 331 310 191 2,058

NOXemissions (t/103t) 0.43 0.45 0.26 0.21 0.08 0.73 0.70 0.39

Production (106t) 367 258 473 131 331 310 191 2,061

GHG emissions (t/103t) 243.86 246.23 79.17 98.70 56.42 197.88 204.52 159.19


4expressed in CO


2+ 21 x CH

4)

NB Data only included where gas quantit y and production level are both reported


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OGP

Gas emissions by source(Figures 1.1.2a, 1.2.2a, 1.3.2a, 1.4.2a, 1.5.2a, 1.6.2a)

Energy Flare Fugitive losses Vents Other/unspecifiedE&P

Overall

2011

CO2(106t) 92.07 57.07 0.03 8.09 131.60 288.85

CH4(103t) 192.44 384.45 384.90 462.56 1,205.95 2,630.30

NMVOC (103t) 15.84 138.42 76.02 197.36 583.50 1,011.13

SO2(103t) 50.54 115.59 4.70 12.28 181.35 364.46

NOX(103t) 388.14 29.94 0.00 0.16 445.96 864.20

GHG (106t) 96.11 65.15 8.11 17.81 156.92 344.09

2010

CO2(106t) 95.64 63.83 0.15 6.47 131.27 297.37

CH4(103t) 190.45 375.56 280.52 590.00 1,121.40 2,557.93

NMVOC (103

t) 19.43 183.50 55.27 153.21 623.13 1,034.53SO

2(103t) 49.77 110.51 0.02 4.10 197.97 362.37

NOX(103t) 387.16 32.13 0.03 1.09 439.82 860.22

GHG (106t) 99.64 71.72 6.04 18.86 154.82 351.08

2009

CO2(106t) 74.48 62.77 0.03 4.24 149.82 291.34

CH4(103t) 53.34 400.30 229.17 544.54 1,190.96 2,417.41

NMVOC (103t) 22.98 191.45 42.28 240.84 574.43 1,071.99

SO2(103t) 45.92 123.31 0.00 14.47 186.43 370.13

NOX(103t) 350.02 38.28 0.00 0.15 428.81 817.26

GHG (106t) 75.60 71.17 4.84 15.68 174.81 342.11

Emissions were categorised by source for the first time in the 2009 database. Emissions are no longer categorised by activity.

Gas emissions in production activi ties per unit of hydrocarbon production (tonnes per thousand tonnes) onshore and of fshore

CO2

CH4

NMVOC SO2

NOX

GHG

Onshore Offshore Onshore Offshore Onshore Offshore Onshore Offshore Onshore Offshore Onshore Offshore

2011

Emissions (t/103t) 154.34 120.27 1.60 1.07 0.65 0.45 0.32 0.10 0.52 0.35 187.73 141.96

Production (106t) 771 1,187 766 1,142 734 1,097 765 1,113 768 1,113 771 1,187

2010

Emissions (t/103t) 134.00 125.00 1.20 1.13 0.61 0.45 0.27 0.11 0.46 0.34 159.16 147.83

Production (106t) 835 1,211 832 1,164 802 1,106 822 1,106 828 1,106 835 1,211

2009

Emissions (t/103t) 139.53 125.71 1.29 1.02 0.67 0.46 0.29 0.12 0.45 0.33 166.64 146.47

Production (106t) 753 1,217 751 1,185 715 1,141 737 1,141 740 1,141 753 1,217

NB Data only included where gas quantit ies in production activitie s and production levels are both reported GHG: Total greenhouse gases (CO

2+ CH

4expressed in CO


2+ 21 x CH

4)


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OGP

Energy Consumption

Energy consumption per unit of hydrocarbon production (Figure 2.1)

2011 2010 2009 2008 2007

% Onsite combustion 80 80 80 79 78

% Purchased 4 5 5 4 5

% Unspecified 15 16 16 17 18

Total energy consumption (GJ/t) 1.57 1.47 1.48 1.40 1.47

Production (106t) 1,982 2,092 2,151 2,049 1,899

NB Data only included where energy consumption and production level are both reported.

Gross energy consumption (million GigaJoule) by region

Onsite Purchased Unspecified Total2011

Africa 355.47 16.24 88.52 460.24

Asia/Australasia 398.98 9.08 192.89 600.95

Europe 473.14 30.2 7.82 511.16

FSU 91.89 0.92 43.82 136.63

Middle East 154.33 12.06 15.96 182.35

North America 729.34 54.35 116.22 899.91

South America 308.26 10.17 11.42 329.85

2010

Africa 366.88 15.14 84.64 466.66


Europe 475.16 27.58 8.26 511.01

FSU 90.15 1.56 42.26 133.96

Middle East 83.48 8.35 16.78 108.62

North America 749.8 75.3 122.7 947.8

South America 337.55 9.84 9.14 356.53

2009

Africa 333.53 14.91 80.32 428.75


Europe 490.5 27.17 7.35 525.03

FSU 97.85 2.97 37.63 138.45

Middle East 302.31 12.39 17.93 332.63

North America 719.63 67.47 127.99 915.08

South America 306.79 9.67 6.49 322.96


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OGP

Energy consumption per unit of hydrocarbon production (GigaJoules per tonne) by region

AfricaAsia/


AmericaSouth

America Overall

2011

% Onsite combustion 77.2 66.4 92.5 67.3 84.6 81.1 93.4 80.4

% Purchased 3.53 1.51 5.98 0.67 6.61 6.04 3.10 4.27

% Unspecified 19.26 32.11 1.55 32.07 8.78 12.91 3.48 15.32

Total energy consumption (GJ/t) 1.33 1.72 1.14 1.11 0.78 3.06 1.69 1.57

Production (106t) 345 350 444 123 233 294 194 1,982

2010


% Purchased 3.25 1.73 5.41 1.16 7.68 7.95 2.77 4.79

% Unspecified 18.20 34.09 1.62 31.55 15.51 12.95 2.57 15.40


Production (106t) 401 386 473 120 181 328 202 2,092

2009


% Purchased 3.49 1.56 5.18 2.14 3.72 7.38 3.00 4.49

% Unspecified 18.82 43.06 1.40 27.18 5.41 13.99 2.02 15.78


Production (106t) 378 326 468 131 333 326 190 2,151

NB Data only included where energy and production level are both reported.Production is the total HC production for data sets where one of onsite, purchased or unspecified energy is reported.

Energy consumption per unit of hydrocarbon production (GigaJoules per tonne) onshore and of fshore

2011 2010 2009

Onshore (GJ/t) 2.24 2.07 2.21

Offshore (GJ/t) 1.27 1.10 1.02

Unspecified (GJ/t) 1.30 1.65 1.47

Overall (GJ/t) 1.57 1.47 1.48

NB Data only included where energy and production levels are both reported


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OGP

Flaring

Hydrocarbon flared per unit of production (tonnes per thousand tonnes)

2011 2010 2009 2008 2007 2006

Hydrocarbon flared t/103tonnes 15.73 16.02 17.59 18.75 20.44 23.90

Production 106tonnes 2,176 2,235 2,327 2,080 2,041 1,735

Flaring per unit of hydrocarbon production (tonnes per thousand tonnes) by region

AfricaAsia/


AmericaSouth

America Overal l

2011

Total flared (t/103t) 50.73 17.56 3.64 11.69 6.43 3.42 11.29 15.73

Production (106

t) 382 345 443 121 410 283 193 2,1762010

Total flared (t/103t) 52.93 15.11 3.96 7.51 8.50 2.26 13.01 16.02

Production (106t) 400 366 471 119 352 326 202 2,235

2009

Total flared (t/103t) 56.54 23.20 3.59 7.60 9.51 2.26 19.95 17.59

Production (106t) 377 325 471 131 507 325 191 2,327

NB Data only included where flaring and production levels are both reported

Aqueous discharges

Oil discharged per unit of produced water discharged (milligrammes oil per litre of produced water discharged) (Figure 4.1a)

2011 2010 2009 2008 2007 2006 2005

Onshore 8.12 14.28 11.61 12.80 17.49 7.71 10.33

Offshore 12.22 12.85 13.64 14.84 15.48 17.47 21.48

Unspecified 14.56 14.60 12.98 21.64 18.84 24.86 20.52

Overall 11.85 13.15 13.34 14.77 15.84 16.40 19.87

NB Data only included where oil in produced water and produced water quantity are both reported


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OGP

Oil content of produced water discharged (Figures 4.1b, 4.1c)

AfricaAsia/


AmericaSouth

America Overall

2011

Onshore

Oil discharged (t/106t) 3.17 5.52 2.06 1.68 80.08 29.70 0.34 8.12

PW discharged (106t) 1.58 73.63 4.62 1.19 0.02 13.23 6.74 101.01

Offshore


PW discharged (106t) 106.94 280.06 222.23 0.05 8.12 31.98 108.27 757.65

Unspecified

Oil discharged (t/106t) 9.86 12.45 0.00 no data no data 33.19 no data 14.56

Production (106t) 26.18 1.20 0.21 0.00 0.00 6.92 0.00 34.51

OverallOil discharged (t/106t) 14.97 10.87 10.81 1.62 11.93 19.93 9.73 11.85

PW discharged (106t) 134.69 354.90 227.06 1.24 8.14 52.13 115.00 893.17

Total PW (106t) 297 297 341 97 245 235 186 1,699

2010

Onshore


PW discharged (106t) 16.29 90.23 4.57 0.16 0.20 22.15 0.61 134.21

Offshore


PW discharged (106t) 117.73 294.37 269.79 0.02 6.54 33.67 112.36 834.47

Unspecified

Oil discharged (t/106t) 13.61 15.87 0.00 no data no data 14.33 no data 14.60

Production (106t) 27.63 28.54 0.39 0.00 0.00 12.12 no data 68.69

Overall


PW discharged (106t) 161.66 413.14 274.75 0.18 6.74 67.94 112.96 1,037.37

Total PW (106t) 392 376 458 111 191 307 201 2,036

2009

Onshore


PW discharged (106

t) 17.48 92.43 5.05 0.06 0.31 18.80 0.65 134.79Offshore


PW discharged (106t) 109.36 301.29 280.33 0.23 7.27 34.25 106.28 839.02

Unspecified

Oil discharged (t/106t) 14.75 3.55 3.35 0.00 no data 10.14 no data 12.98

Production (106t) 27.42 0.38 0.35 0.06 no data 14.31 0.00 42.52

Overall


PW discharged (106t) 154.27 394.10 285.74 0.35 7.58 67.37 106.93 1,016.33

Total PW (106t) 339 314 439 106 224 301 190 1,912

NB Data only included where oil discharges and produced water discharges are both reported Business Units record all oil in produced water discharged to unlined evaporatio n ponds as being discharged to surface water


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OGP

Oil discharged per unit of hydrocarbon production (Figure 4.2a)

2011 2010 2009 2008 2007 2006 2005

Onshore 2.41 3.16 3.02 3.62 5.65 2.04 2.1Offshore 8.79 9.14 10.17 11.08 12.18 13.43 13.83

Overall 6.47 6.99 7.48 8.54 9.77 9.64 9.22

Oil discharged per unit of hydrocarbon production (Figures 4.2b, 4.2c)

AfricaAsia/


AmericaSouth

America Overall

2011

Onshore


Production (106t) 65 71 21 44 114 141 50 506

Offshore


Production (106t) 187 258 342 43 134 65 141 1,169

Unspecified


Production (106t) 59 8 68 10 no data 43 no data 189

Overall


Production (106t) 311 337 431 97 248 249 191 1,865

2010

OnshoreOil discharged (t/106t) 6.23 9.41 0.09 0.09 0.02 4.35 0.03 3.16

Production (106t) 69 74 80 52 111 177 43 607

Offshore


Production (106t) 244 267 367 50 51 53 142 1,173

Unspecified


Production (106t) 79 24 11 9 no data 48 no data 171

Overall


Production (106t) 392 364 458 111 162 278 185 1,951

2009

Onshore


Production (106t) 43 65 59 46 103 158 44 518

Offshore


Production (106t) 218 237 368 53 53 67 129 1,126

Unspecified

Oil discharged (t/106t) 5.23 0.12 0.10 0.00 no data 2.94 0.00 3.25

Production (106

t) 77 11 12 20 no data 49 1 170Overall


Production (106t) 339 313 439 119 156 273 175 1,814

NB Data only included where oil discharges and production level are both reported


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OGP

Percent of produced water re-injected overall (expressed as percent total produced water generated) (Figure 4.3a)

2011 2010 2009 2008 2007 2006 2005

Onshore 90 90 89 88 89 90 89Offshore 23 22 18 17 16 19 10

Overall 65 65 63 63 64 61 62

Percent of produced water reinjected overall (tonnes per tonne) (Figures 4.3b, 4.3c)

AfricaAsia/


AmericaSouth

America Overall

2011

Onshore 84 87 94 65 81 95 97 90

Offshore 19 14 29 97 84 0 12 23

2010

Onshore 90 87 94 88 85 93 100 90

Offshore 10 17 31 98 82 3 5 22

2009

Onshore 75 86 94 87 76 94 100 89

Offshore 5 14 25 57 78 11 4 18


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OGP

Ratio of produced water reinjected to produced water discharged (tonnes per tonne) by region

AfricaAsia/


AmericaSouth

America Overall

2011

Onshore

PW reinjected (t/t) 5.09 6.73 14.54 1.84 4.38 18.33 38.32 8.54

Offshore

PW reinjected (t/t) 0.24 0.16 0.40 32.37 5.41 0.00 0.14 0.30

Unspecified

PW reinjected (t/t) 0.51 6.29 6.55 no data no data no data no data 0.72

Overall

PW reinjected (t/t) 0.36 1.73 0.78 2.71 4.53 6.03 2.38 1.84

2010

Onshore

PW reinjected (t/t) 8.80 6.43 15.19 7.27 5.66 13.57 374.04 8.80

Offshore

PW reinjected (t/t) 0.12 0.21 0.45 50.91 4.54 0.03 0.05 0.28

Unspecified

PW reinjected (t/t) 0.54 3.07 4.33 42.13 no data 0.64 no data 0.71

Overall

PW reinjected (t/t) 0.56 1.84 0.76 13.42 5.51 5.86 2.05 1.89

2009

Onshore

PW reinjected (t/t) 3.02 6.37 14.59 6.77 3.17 15.21 326.83 7.70Offshore

PW reinjected (t/t) 0.05 0.16 0.34 1.32 3.63 0.12 0.04 0.22

Unspecified

PW reinjected (t/t) 0.33 10.91 5.07 13.26 no data 0.16 no data 0.69

Overall

PW reinjected (t/t) 0.49 1.90 0.65 6.29 3.24 5.41 2.11 1.67

NB Data only included wher

2011 environmental ogp

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