2012 Environmental OGP

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ENVIRONMENTAL PERFORMANCE INDICATORS 2012 DATAReport No. 2012e(November 2013)

OGP DATA SERIES

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 guidelinesor 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 andregulations 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 eff ort 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 writtenpermission 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 indicators2012 data

Report No: 2012e

November 2013


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Te environmental statistics for 2012 were derived from data provided by the following companies:

Contributing companiesAddax Petroleum Limited

ADNOC

BG

BHP Billiton

BP

Cairn Energy

Chevron

CNOOC

ConocoPhillips

Dolphin EnergyDONG E&P

E.ON

Eni E&P Division

ExxonMobil

GDF SUEZ E&P International

Hess Corporation

Husky

INPEX

Kosmos

Kuwait Oil CompanyMaersk Oil

Marathon Oil Company

MOL

Nexen

Oil Search

OMV

Pan American Energy

Perenco

Petrobras

Petronas

Premier OilP EP

Qatar Petroleum

Repsol

RWE

Sasol

Shell Companies

Statoil

Suncor

alisman Energy

otalullow

Wintershall


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Environmental performance indicators 2012 data

OGP

able o contents

Executive summary iiGaseous emissions ....................................................................................................................................ii

Energy consumption.................................................................................................................................iiFlaring .....................................................................................................................................................iiiAqueous discharges ..................................................................................................................................iiiNon-aqueous drilling fluids retained on cuttings discharged to sea .........................................................iiiSpills .....................................................................................................................................................iii

Introduction 1

Scope of data submissions 2

1 Gaseous emissions 61.1 Carbon Dioxide (CO

2) .......................................................................................................................8

1.2 Methane (CH4) ..................................................................................................................................9

1.3 Greenhouse Gas (GHG) ..................................................................................................................101.4 Non-Methane Volatile Organic Compounds (NMVOCs) ...............................................................111.5 Sulphur dioxide (SO

2) ......................................................................................................................12

1.6 Nitrogen oxides (NOX

) ....................................................................................................................13

2 Energy consumption 14

3 Flaring 16

4 Produced Water 174.1 Quality (oil content) of produced water discharges...........................................................................184.2 Quantity of oil discharged in produced water per unit of production ...............................................194.3 Produced Water Injection ................................................................................................................21

5 Non-Aqueous Drilling Fluids retained on cuttings discharged to sea 235.1 Non-Aqueous Base Fluid retained on cuttings discharged to sea ......................................................23

6 Spills 256.1 Oil Spills ..........................................................................................................................................25

Appendix A Data tables 31Scope of data submissions .......................................................................................................................311. Gaseous emissions ............................................................................................................................332. Energy Consumption .......................................................................................................................363. Flaring .............................................................................................................................................37

4. Produced Water ...............................................................................................................................385. Non-Aqueous Drilling Fluids retained on cuttings discharged to sea ...............................................446. Spills ................................................................................................................................................45

Appendix B Glossary 53


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International Association of Oil & Gas Producers

OGP

Over the past 14 years the 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 2012. Data have been submitted or the report by 43 o OGPs62 member operating companies working in 78 countries worldwide. Tis total includes 3 companiesreporting or the first time this year and 40 o the 41 companies that contributed data in 2011. Inormationis aggregated at both global and regional levels and is expressed within 6 environmental indicator categories:

Gaseous emissions;

Energy consumption;

Flaring;

Aqueous discharges; Non-aqueous drilling fluids retained on cuttings discharged to sea; and

Spills o oil and chemicals.

Tese data represent oil and gas wellhead production o 2 232 645 thousand tonnes (in the region o 16.6billion BOE), about 32% o 2012 global production sales. Tis is a 1% increase in the production representedin this report compared with 2011. However, regional coverage is uneven, ranging rom almost all known

production in Europe to 8% in the Former Soviet Union (FSU).

Gaseous emissions

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

processing operations. In 2012 participating OGP member companies reported emissions o: 253 million tonnes o carbon dioxide (CO

2)equivalent to 132 tonnes o carbon dioxide per thousand

tonnes o hydrocarbon production;

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

hydrocarbon production;

817 thousand tonnes o non-methane volatile organic compounds (NMVOC)equivalent to 0.5tonne o NMVOC per thousand tonnes o hydrocarbon production;

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

2per thousand tonnes o

hydrocarbon production; and

796 thousand tonnes o nitrogen oxides (NOX

)equivalent to 0.4 tonne o NOX

per thousand tonneso hydrocarbon production.

Normalised CH4emissions increased in 2012 by 6% compared with 2011.

Normalised NOX

emissions increased in 2012 by 5% compared with 2011.

Normalised NMVOC emissions decreased in 2012 by 4% compared with 2011.

Normalised CO2emissions and normalised SO

2remained virtually unchanged compared with 2011.

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 2012, OGP reporting companies consumed on average 1.4 GigaJoules o energy or every tonne ohydrocarbon produced; a 9% reduction compared with the 2011 average. As in previous years, data indicatethat onshore production in 2012 was more energy intensive than offshore production.

Executive summary

Source: BP Energy Review 2013


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Flaring

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 2012, 13.9 tonnes o gas was flared or every thousand tonnes o hydrocarbon produced versus 15.7 tonnesin 2011 and 16.0 in 2010. 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.

Aqueous discharges

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

o hydrocarbon produced in 2012 (including oil, condensates and gas), 0.5 tonne o produced water wasdischarged and 0.9 tonne o produced water was re-injected.

Te quality o produced water discharges is measured in terms o oil content. In 2012, the averageconcentration o oil in produced water was 6.8 mg/l or onshore discharges and 14.1 mg/l or offshoredischarges. When expressed in terms o oil production, overall, these discharges are equivalent to 7.0 tonneso oil or every million tonnes o hydrocarbon produced.

Comparison with 2011 data indicates that the average concentration o oil in produced water dischargedincreased in 2012 by 14%. Te average quantity o oil discharged per unit o hydrocarbon productionincreased by 10%. Tese variations reflect a change in the companies reporting data or oil and produced

water discharges.

Non-aqueous drilling fluids retained on cuttings discharged to sea

While much o the offshore dril ling is achieved using water-based dril ling fluids, some technicalrequirements during well dril ling operations avour the properties that are only available rom non-aqueousdrilling fluids (NADFs) . In 2012 reporting companies discharged 20 523 tonnes o non-aqueous basefluids (NABF) on drill cuttings to sea. O these discharges, 89% contained Group III base fluids and 4%contained Group II fluids, the reporting Group was not given or the remaining 7%. Tere have been noreports o discharges o Group I fluids retained on cuttings since the reporting o NABF by Group I, II andIII classification began in 2003.

Spills

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

In 2012, participating OGP member companies reported 1 680 oil spills greater than 1 barrel in size, resultingin a normalised spill rate o 0.8 oil spills per million tonnes o hydrocarbon production (1.5 in 2011).

Te reported oil spills >1 barrel resulted in the release o a total o 9 483 tonnes o oil. Te quantity o oilspilled per unit o hydrocarbon production has allen to 4.8 tonnes per million tonnes production, 40%lower than the rate or 2011 and 6% higher than the rate or 2010 .

Deinitions o Group I, II and III base luids are provided in section 5.1 his does not include any data related to the Deepwater Horizon incident, which is the subject o on-going, Multi-District litigation.


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Over the past 14 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 sixcategories:

Gaseous emissions;

Energy consumption;

Flaring;

Aqueous discharges;

Non-aqueous drilling fluids retained on cuttings discharged to sea; 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 bythe OGP membership. Tese definitions align with the IPIECA/API/OGP il and gas industry guidanceon oluntary sustainability reporting, OGP report number 437. Te definitions are provided via a usersguide that is reviewed at regular intervals and updated to reflect improvements in reporting and to provideadditional clarification.

Annual reports o activities in the years 2003 to 2011 and summary reports or activities in 2001 and 2002 havepreviously been published and are available rom the OGP website at http://www.ogp.org.uk/publications.

Introduction


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Scope o data submissions

Forty three OGP member companies reported environmental inormation or, on average, six countrieseach. Data rom 78 countries are represented in the report. Te data represent 2 233 million tonnes ohydrocarbon production, approximately equivalent to 32% o 2012 world production as reported in the BP

Statistical Review 2013.

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

Figure 0-1:2012 regional coverage

Figure 0-2: Percentage o nown pro uction in t is ata ase

Middle East19%

Asia/Australasia 14%

NorthAmerica 14%

Africa 23%

Europe 17%

FSU 5%South & CentralAmerica 8%

Note: The country of Georgia is now reported as part of the FSU region (previously Europe). In this report the change affects gross atmosphericemissions and energy for the two regions for the year 2011 only. Reported production for Georgia was two thousand tonnes or less for the years20012004 and 2006, and 119 thousand tonnes in 2007. Some normalised results published in previous reports are slightly affected for the regionsof FSU and Europe:

CO2, NMVOC and NOXemissions per unit of production for the two regions for the years 2002, 2003, 2006 and 2007.

Spills per unit of production onshore for the years 2006 and 2007.

Energy per unit of production, specifically onsite combustion, for 20012007 excluding 2005. Hydrocarbon flared per unit of production 2007 only.

20% 32

16

14 22 15

23

9

28

35%

3378%

70

8596%

2423%

7139%

8%

11North America Europe

Africa

Former Soviet Union

Asia/AustralasiaMiddle EastSouth & Central America

In this context a data set is a set of data with distinct company, country and location (onshore/offshore) where there is both hydrocarbon production dataand a positive return (zero or greater) of either atmospheric emissions, aqueous discharges, energy consumption, hydrocarbon flared or spills.

Number of companies providing data

% of known production (as reported in BP Statistical Review)Note: Production figures given in this r eport relate to gross production whereas world data extracted from the BP Statistical Review represent net production. Thus the data are not direct-ly comparable, but the percentage of world production figures are given as indicative of the relative regional contr ibutions in the database.%

n

nCountry represented/Not represented

N.B. Regional allocations for some countries differ from those used in the OGP Articles of Association.

Figure 0-3: Percentage o tota ata sets in t is ata aseFSU 3%

Asia/Australasia 22%

North America10%

South & CentralAmerica 10%

Middle East 7%

Europe 26%

Africa 21%


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Fig 0-4: Production associated with OGP database and 2012 production in BP Statistical Review of World Energyby regionPercentage of known production

0

20

40

60

80

100

South &Central America

NorthAmerica

MiddleEast

FSUEuropeAsia/Australasia

Africa

96

78

111

3935

23 20

8

Production figures in this report represent wellhead production, which includes oil and gas volumes consumed in operations. The BP Statistical Reviewprovides data on production exported for sale..

Tis report only reflects the perormance o the OGP member companies that have provided data. Howeverwhere the degree o coverage is highestor 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 & Central America, the data give a broad indication o industry perormance.

For the Middle East and North America, the regional coverage is less comprehensive, giving a weakerindication o industry perormance. For the Former Soviet Union (FSU), data reported by participatingcompanies represent just 8% o the total sales production or that region and thus may not be representativeo the regions perormance.

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.


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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 the analyses willcover less than 100% o the total production reported because some companies did not submit data or all

metrics covered in the survey. Tis is particularly relevant to the South & Central American region wherearound 40% o the submitted data are included in the normalised emissions, energy consumption, flaringand oil discharges results, and to the Middle East region where around 55% o emissions and oil dischargesare included in the normalised results. Coverage or the analyses is presented below.

Table 0-1:Percentage of reported production included in normalised analyses

AfricaAsia/

Australasia Europe FSUMiddle

EastNorth

America

South &Central

AmericaAll

regions

Gas emissions:

CO2

CH4

NMVOC

SO2

NOX

Energy consumed

Flaring

Oil discharged in produced water

Oil spills

Green (90%-100%): data fairly representative of region; Yellow (65%-89%): data moderately representative; Orange (30%-64%): data poorlyrepresentative; Red (0%-30%): data not representative of region

Table 0-2:Production associated with OGP database and 2012 production in BP Statistical Review of World Energyby region

AfricaAsia/

Australasia Europe FSUMiddle

EastNorth

America

South &Central

AmericaAll

regions

Percent of production for whichdata are reported, by region

78% 39% 96% 8% 23% 20% 35% 32%

In 2009, data on the source types o gaseous emissions (energy, flare, vent, ugitive emissions and other) werecollected or the first time. It was recognised that not all participating companies would be able to contributedata at that level o detail in the beginning; nevertheless, data broken down by source cover roughly hal othe gaseous emissions reported or 2009, 2010, 2011 and 2012. It is expected that this inormation will behelpul in understanding some o the trends in the data as well as to help indicate areas or improvement.

Data coverage or the breakdown is expected to improve over time.

Te current year data shown in this report are based on the best available inormation that membercompanies are able to provide at time o publication. In some cases reporting companies have providedcorrections to previous years data, and the changes have been included in this report where they affect

previously published regional or global results. Te results affected are listed in Appendix A.


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Detailed Review


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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, process saety events and emergency flaringand gas venting.

Gaseous emissions covered in this report are those considered most relevant rom process control as well asregulatory perspectives. Tey are:

CO2: carbon dioxide released to the atmosphere rom any source. Carbon monoxide (CO) is not

included.

CH4: methane released to the atmosphere, rom any source, including ugitive losses.

Green house gas is CO2+ CH

4expressed as CO

2equivalent.

NMVOCs: Non-Methane Volatile Organic Compounds are all hydrocarbons, other than methane,released to the atmosphere.

SO2: sulphur dioxide. NO

X: the sum o nitric oxide (NO) and nitrogen dioxide (NO

2) expressed as NO

2equivalent. Nitrous

oxide (N2O) is not included as a component o NO

X.

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

Emissions rom the generation o purchased energy (electricity, steam) are not reported.

Normalised figures or 2012 emissions (see Figure 1-1) are broadly consistent with data published or

activities in 20062011: 132 tonnes o carbon dioxide (CO2) per thousand tonnes o hydrocarbon production;

1.3 tonnes o methane (CH4) per thousand tonnes o hydrocarbon production;

0.5 tonne o non-methane volatile organic compounds (NMVOC) per thousand tonnes o hydrocarbonproduction;

0.2 tonne o sulphur dioxide (SO2) per thousand tonnes o hydrocarbon production; and

0.4 tonne o nitrogen oxides (NOX

) per thousand tonnes o hydrocarbon production.

Gaseous emissions

ee or example:etroleum ndustry uidelines or Reporting reenhouse as missions (2003) oint PIECA/PI/GP report (inrevision);angeaMnergy and missions stimating ystem, PI, http://ghg.api.org;


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In 2012, participating OGP member companies reported emissions o: 253 million tonnes o CO

2;

2.3 million tonnes o CH4

;

817 thousand tonnes o NMVOC;

303 thousand tonnes o SO2; and

796 thousand tonnes o NOX

Figure 1-1: Emissions per thousand tonnes hydrocarbon productiontonnes per thousand tonnes

0.0

0.5

1.0

1.5

NOX

SO2

NMVOCCH4

1.33

0.48

0.17

0.43

2012

2011

2010

2009

2008

2007

2006

Figure 1-2: CO2and CH

4expressed as CO

2equivalent per thousand tonnes hydrocarbon production

tonnes per thousand tonnes

0

50

100

150

200

2012201120102009200820072006

132

28

CH4expressed as CO

2equivalent

(CH4x 21)

CO2

Note: As nitrous oxide, hydrofluorocarbons, perfluorocarbons and sulphur hexafluoride contribute only a small fraction of greenhouse gas emissions from E&P

activities, they have not been included here.

Te ollowing sub-sections present the overall emission data or the years 2006 to 2012, regional emissiondata or 2008 to 2012 and atmospheric emissions categorised by the source o the gas release or the years2011 and 2012. Te reporting options or the allocation o source categories are Energy, Flare, Vents,Fugitive losses and Other/unspecified (see Glossary at Appendix B).


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. 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 o production

Global CO2 emissions normalised to

hydrocarbon production or 2012 were132 tonnes o CO

2 per thousand tonnes o

production, virtually unchanged comparedwith 2011, as shown in Figure 1.1.1.1.

Regional averages or the quantity o carbondioxide emissions per unit o production varyrom 58 to 214 tonnes o carbon dioxide perthousand tonnes o hydrocarbon production,as shown in Figure 1.1.1.2. In 2011 the range

was between 48 and 206 tonnes per thousandtonnes o production.

.. missions by source

Te source was specified or59% o the carbon dioxideemissions reported or 2012.

As shown in Figure 1.1.2.1, 61%o the reported carbon dioxideemissions where the source wasspecified were rom energy use,33% were rom flaring and 6%

were rom venting.

0

20

40

60

80

100

120

140

160

142 142 142

135 133 132 132

2006 2007 2008 2009 2010 2011 2012

Figure 1.1.1.1: CO2emissions per unit of production

tonnes per thousand tonnes of hydrocarbon production

Vents6%

Fugitive losses 0.02%

Flare 33%

Energy 61%

Figure 1.1.2.1: CO2emissions by source2012

0

50

100

150

200

250

300


NorthAmerica

MiddleEast


Africa

158

151

58

83

214

102

93

Overall 132

2012

2011

2010

Figure 1.1.1.2: CO2emissions per unit of production tonnes per thousand tonnes of hydrocarbon production

Note: excludes emissions where the source is not specified


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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.


Global CH4 emissions normalised to

hydrocarbon production or 2012 showa 7% increase compared with 2011, asindicated in Figure 1.2.1.1. Tis is partlydue to asset acquisitions in NorthAmerica and an increase in CH

4

emissions in Europe.

Regional averages or methaneemissions expressed per unit o

production vary rom 0.2 to 2.7tonnes o methane per thousandtonnes o hydrocarbon production, as

shown in Figure 1.2.1.2. In 2011 therange was between 0.2 and 2.8 tonnes

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 incertain types o production acilities.


Te source was specified or 36% o the totalmethane emissions reported in 2012.

Where the source was specified, 38%o methane emissions were rom vents(including venting, vessel loading, tankstorage, etc.), 33% were rom ugitive losses,24% were rom flaring and 5% were romenergy use, as shown in Figure 1.2.2.1.

0.0

0.2

0.4

0.6

0.8

1.0

1.2

1.4

2012201120102009200820072006

1.18

1.24

1.33

1.001.04

1.02

1.14

Figure 1.2.1.1: CH4emissions per unit of production


0.0

0.5

1.0

1.5

2.0

2.5

3.0


NorthAmerica

MiddleEast


Africa

2.

68

0.

52

0.

61

0.

16

2.5

8

1.

21

0.

83

Overall 1.3

2012

2011

2010

Figure 1.2.1.2: CH4emissions per unit of production tonnes per thousand tonnes of hydrocarbon production

Vents38%

Fugitive losses33%

Flare24%

Energy5%

Figure 1.2.2.1: CH4emissions by source2012



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. Greenhouse Gas (GHG)

For E&P activities, CO2and 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 conversion to CO

2 equivalent

(GHG = CO2+ 21 x CH

4).


Participating companies reported

normalised emissions o 160 tonnes oGHG per thousand tonnes o hydrocarbon

production in 2012. Tis represents a 1%increase in intensity compared with 2011results (see Figure 1.3.1.1).

Regional averages or quantityo greenhouse gas emissions perunit o production vary rom61 to 268 tonnes o greenhousegas per thousand tonnes ohydrocarbon production, as

shown in Figure 1.3.1.2. In2011 the range was between 51and 243 tonnes per thousandtonnes o production.


Te source was specified or 55% o the totalreported greenhouse gas emissions.

Where the source is specified, 55% o thereported greenhouse gas emissions are romenergy use, 32% are rom flaring, 9% arerom venting or vents and 4% are attributableto ugitive losses, as shown in Figure 1.3.2.1.

HG: otal reenhouse ases (O2

+ H4expressed as O

2equivalent)

0

30

60

90

120

150

180

2012201120102009200820072006

163 164 163159 160158 158

Figure 1.3.1.1: GHG emissions per unit of production


0

50

100

150

200

250

300


NorthAmerica

MiddleEast


Africa

183 2

07

94

61

268

110

115

Overall 160

2012

2011

2010

Figure 1.3.1.2: GHGemissions per unit of production tonnes per thousand tonnes of hydrocarbon production

Vents9%

Fugitivelosses 4%

Flare32%

Energy55%

Figure 1.3.2.1: GHG emissions by source2012



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. 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 o productionGlobal NMVOC emissions normalisedto hydrocarbon production or 2012 were0.48 tonnes per thousand tonneso hydrocarbon, a 2% reductioncompared with 2011 results. SeeFigure 1.4.1.1.

Regional averages or quantityo NMVOC emitted per unito production vary rom 0.22 to

0.71 tonnes per thousand tonneso hydrocarbon production, asshown in Figure 1.4.1.2. In 2011the range was between 0.18 and0.82 tonnes per thousand tonneso production.


Te source was specified or 48%o the total NMVOC emissionsreported in 2012.

Where the source is specified, 47%o NMVOC emissions reported or2012 come rom venting or vents,32% rom flaring, 17% rom ugitivelosses and 4% rom energy use, as

shown in Figure 1.4.2.1.

0.0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

2012201120102009200820072006

0.50 0.49 0.48

0.700.68

0.58

0.53

Figure 1.4.1.1: NMVOC emissions 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

0.7

0.8

0.9


NorthAmerica

MiddleEast


Africa

0

.70

0.2

4

0.2

2

0.3

5

0.5

9

0.4

2

0.7

1

Overall 0.48

2012

2011

2010

Figure 1.4.1.2: NMVOC emissions per unit of production tonnes per thousand tonnes of hydrocarbon production

Vents47%

Fugitive

losses 17%

Flare32%

Energy4%

Figure 1.4.2.1: NMVOC emissions by source2012



20/6412


OGP

. Sulphur dioxide (SO)

Sulphur dioxide emissions by the E&P industry

arise through oxidation during combustion osulphur naturally contained within hydrocarbonuels or flared gas. Te rate o emission thereoreis principally a reflection o the sulphur contento produced hydrocarbons, which varies widelydepending on the nature o the hydrocarbon

produced.


Global SO2 emissions normalised to

hydrocarbon production or 2012 were 0.17tonnes per thousand tonnes o hydrocarbon

production, virtually unchanged compared with2011 results. See Figure 1.5.1.1.

Regional averages or quantity o SO2emissions

expressed per unit o production varyrom 0.03 to 0.64 tonne per thousandtonnes o hydrocarbon production,as shown in Figure 1.5.1.2. In 2011the range was between 0.03 and0.54 tonne per thousand tonnes o

production.


Te source was reported or 47% o thetotal SO

2emissions in 2012.

Where the source was specified, 63% osulphur dioxide emissions reported in2012 were rom flaring, 33% were romenergy use and 4% were rom venting or

vents, as shown in Figure 1.5.2.1.

0.00

0.05

0.10

0.15

0.20

0.25

2012201120102009200820072006

0.17 0.17 0.17

0.20

0.18 0.18 0.18

Figure 1.5.1.1: 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

0.7


NorthAmerica

MiddleEast


Africa

0.0

3

0.2

8

0.0

4

0.6

4

0.1

7

0.0

7

Overall 0.17

2012

2011

2010

0.1

9

Figure 1.5.1.2: SO2emissions per unit of production


Vents4%

Fugitive losses0%

Flare63%

Energy33%

Figure 1.5.2.1: SO2emissions by source2012



21/6413


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 oproduction

Global NOX

emissionsnormalised to hydrocarbon

production or 2012 were 0.43tonnes per thousand tonnes o

production, 5% higher than the2011 result. Tis is largely due toan increase in drilling activity,and improved record keeping

in North America. See Figure1.6.1.1.

Normalised NOX

emissions arehighest in the North Americaregion, with an average o 0.83tonne o NO

X per thousand

tonnes o hydrocarbonproduction, reflecting the higherenergy intensity. Te MiddleEast region has the lowestnormalised NO

Xemissions o 0.13

tonne NOX per thousand tonneso hydrocarbon production, asshown in Figure 1.6.1.2. In 2011the range was between 0.15 and0.77 tonne per thousand tonnes o

production.


Te source was reported or46% o the total nitrogen oxideemissions reported in 2012.

Where the source was specified,94% o nitrogen oxide emissionsreported in 2012 were rom energyuse. Te remaining 6% were romflaring, as shown in Figure 1.6.2.1.

0.0

0.1

0.2

0.3

0.4

0.5

2012201120102009200820072006

0.40

0.38

0.41 0.41 0.41

0.43

0.39

Figure 1.6.1.1: 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

0.9


NorthAmerica

MiddleEast


Africa

0.

41

0.

33

0.

23

0.

13

0.

83

0.6

2

Overall 0.43

0.

43

2012

2011

2010

Figure 1.6.1.2: NOXemissions per unit of production tonnes per thousand tonnes of hydrocarbon production

Vents 0.1%

Flare6%

Energy94%

Fugitive losses0%

Figure 1.6.2.1: NOXemissions by source2012



22/6414


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 (e.g.at 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 2012, OGP reporting companies consumed on average 1.4 GigaJoules o energy or every tonne o

hydrocarbon produced, as shown in Figure 2.2. Tis is a reduction o 9% compared with the 2011 averageand reflects a change in the companies reporting data and in the number o assets operated.

As in previous years, data indicate that onshore production in 2012 was more energy intensive than offshoreproduction.

Te majority o energy requirements were met by combustion o uels on-site rather than by purchase oelectricity or steam.

Figure 2.1: Energy consumption by source2012

Unspecified

82%Specified

18%

Purchasedenergy 6%

Onsite combustion94%


23/6415


OGP

Figure 2.2: Energy consumed per unit of hydrocarbon production GigaJoules per tonne

0.0

0.3

0.6

0.9

1.2

1.5

1.8 Unspecified energy Purchased energy On-site combustion

2012201120102009200820072006

In Figure 2.3, 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 (3.39GigaJoules per tonne o hydrocarbon produced), while the Middle East was the least energy intensive (0.24GigaJoules per tonne).

Figure 2.3: Energy consumption per unit of hydrocarbon productionby region GigaJoules per tonne

0.0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0


NorthAmerica

MiddleEast


Africa

1.3

3

1.2

4

1.

16

0.2

41.0

1

3.3

9

1.2

5

Overall 1.401.9

0

20122011

2010


24/6416


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 2012, 13.9 tonnes o gas were flared or every thousand tonnes o hydrocarbon produced versus 15.7 in2011 and 16.0 in 2010, as shown in Figure 3.1.

Figure 3.1: Hydrocarbon flared per unit of hydrocarbon production tonnes per thousand tonnes

0

5

10

15

20

25

2012201120102009200820072006

23.9

20.4

18.817.6

16.0 15.7

13.9

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

Figure 3.2: Hydrocarbon flared per unit of hydrocarbon productionby region tonnes per thousand tonnes

0

10

20

30

40

50

60


NorthAmerica

MiddleEast


Africa

35.

29

3.

46

5.1

3

5.5

6

5.3

611.3

10.5

2

Overall 13.93

15.

98

2012

2011

2010

Note: Where hydrocarbon flare could not be separated out total flare figures have been used. In most cases these 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, as wellas a change in the companies reporting flare data, have helped reduce flaring rom 53 tonnes o gas flared orevery thousand tonnes o hydrocarbon produced in 2010 to 35 in 2012.

Flaring


25/6417


OGP

Produced water is the highest volume liquid discharge generated during the production o oil and gas. It consistso ormation water (present naturally in the reservoir), floodwater (previously injected into 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 (includingseas, rivers, lakes, etc.) or to land (including to evaporation ponds). Produced water can also be injected eitherinto the producing reservoir where it can enhance hydrocarbon recovery or into another appropriate ormationor disposal. Te volume o produced water typically increases as recovery o oil and gas rom a field progressesthat is, the field becomes mature. As context, the worldwide volume o produced water reported in thisdatabase in 2012 was approximately 1.5 times that o hydrocarbon production.

Most countries regulate the discharge o produced water taking into account differing environmentalconditions and sensitivities between onshore and offshore.

Te quality o produced water is most widely expressed in terms o its oil content. Tere are a number oanalytical methodologies in use around the world or measuring oil in water. As a result o differences in

analytical methodologies, care should be taken when interpreting aggregated data.

ote 1: or this analysis aqueous discharges fom crude oil and natural gas acilities are categorised by thesource o production and not the location where the discharges occur, in other words, where production is offshoreand discharges are generated fom an onshore acility, the discharges are reported as offshore .

ote 2: or various reasons companies either discharge or re-inject produced water. Te split between theproduced water injected and discharged changes over time and this influences the quantity and quality o oildischarged to surace.

Aqueous discharge covers the discharge o produced water, mainly produced ormation water. In 2012 participating companies reported the oil content o 786 million tonnes o discharged produced

water. Where the location was specified, approximately 89% o water discharged was rom offshoreoperations and 11% was rom onshore operations.

For every tonne o hydrocarbon produced in 2012, 0.5 tonne o produced water was discharged to thesurace and 0.9 tonne o produced water was re-injected. In 2011, 0.5 tonne o produced water wasdischarged to the surace and 1.0 tonne was re-injected.

Te overall average oil content o produced water discharges was 13.5 mg/l, compared with 11.9 mg/l in2011 and 13.1 mg/l in 2010. Offshore the average oil content in produced water was 14.1 mg/l, whilstonshore it was 6.9 mg/l (see Figure 4.1.1).

Overall 7.0 tonnes o oil was discharged per million tonnes o hydrocarbon production in 2012, a 10%increase compared with 2011 (6.3 in 2011 and 7.0 in 2010). Te quantity o oil discharged per unit ohydrocarbon production was 1.9 t/106t onshore and 10.0 t/106t offshore (see Figure 4.2.1).

ote 3: Tere are marked differences in the scope o reporting or each region between the years, onshore and offshore.

Produced Water


26/6418


OGP

. Quality (oil content) of produced water discharges

Figure 4.1.1: Oil discharged per unit of produced water discharged milligrammes oil per litre of produced water discharged

0

5

10

15

20

OverallOnshore

6.

85

Offshore

14.

13

13.

48

Te global quantity o oil discharged per unit o produced water was 13.5 mg/l, a 14% increase comparedwith the 2011 result. Offshore results show a 16% increase compared with 2011. Tis increase is largelydue to a change in the companies reporting offshore data. Onshore the average has decreased by 16%compared with 2011.

Figure 4.1.2: 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

30


NorthAmerica

Middle EastFSUEuropeAsia/Australasia

Africa

10.5

8

Overall 14.13

8.2

0

36.8

8

20.0

8

13.

73

13.

62

2012

2011

2010

Te offshore database or quality o produced water or South & Central America was affected substantiallyby a change in reporting scope.

A very small amount o produced water discharged was reported or the FSU and the Middle East bothonshore and offshore compared with the other regions. Te percentage o produced water re-injected inthese regions was high, see Figures 4.3.2 and 4.3.3.


27/6419


OGP

Figure 4.1.3: 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

30


NorthAmerica

MiddleEast


Africa

2.3

6

5.7

7

1.8

0

1.5

1

23.0

7

34.8

7

80.0

829.

7

64

80

108

Overall 6.85

2012

20112010

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

Figure 4.2.1: Oil discharged per unit of production tonnes per million tonnes of hydrocarbon production

0

3

6

9

12

15

OverallOnshoreOffshore

1.

94

9.

99

6.9

5

2012

2011

2010

2009

2008

2007

2006


28/6420


OGP

Overall the rate o oil discharged per unit o production has increased by 10% compared with 2011. Tis isdue to an 18% increase in the reported quantity o oil discharged offshore, which is influenced by activitiesArica, where new data have been introduced or 2012, and Asia/Australasia.

Regional averages or the quantity o oil discharged by unit o production o hydrocarbons vary, onshore (seeFigure 4.2.3), rom a ew kg per million tonnes in the FSU and Middle East regions to 6.0 t/10 6t in Arica,

while offshore (Figure 4.2.2) they vary rom 0.0 t/106t in the FSU to 18.7 t/106t in Asia/Australasia.

As noted above, the difference between the overall averages onshore and offshore reflects the act thatproduced water is largely re-injected onshore (where environmental sensitivities to produced waterespecially saltare generally high) while the offshore environment is generally less sensitive to produced

water discharges.

Figure 4.2.2: Oil discharged per unit of productionoffshore tonnes per million tonnes of hydrocarbon production

0

4

8

12

16

20


NorthAmerica

MiddleEast


Africa

18.7

2

Overall 9.99

10.9

6

7.8

6

0.3

7

7.9

19.3

6

2012

2011

2010

Note: A very small amount of production was reported for the FSU and the Middle East both onshore and offshore compared withthe other regions. See Scope of data submissions and Section 4 of Appendix A.

Figure 4.2.3: Oil discharged per unit of productiononshore tonnes per million tonnes of hydrocarbon production

0

4

8

12

16

20


NorthAmerica

MiddleEast


Africa

0.7

35.5

0

5.9

5

0.1

5

1.4

2

Overall 1.94

2012

2011

2010


29/6421


OGP

. Produced Water Injection

Figure 4.3.1: Percent of produced water re-injected overall expressed as percent. total produced water generated

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

OverallOnshoreOffshore

2012

2011

2010

2009

2008

2007

2006

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

Offshore (Figure 4.3.2), where, in the majority o locations, de-oiled produced water can be discharged tosea with limited impact, there is much less re-injection (27% in 2012). Exceptions to this include locations

where injection would be beneficial to the management o the reservoir, and water chemistry allows orre-injection, or where environmental sensitivity is considered to be high.

While the average is 27% offshore there is a large variety among the regions. For example participatingcompanies in the FSU and Middle East regions reported more than 90% o the offshore produced waterre-injected, while in North America and South & Central America less than 2% o produced water wasre-injected.

Onshore, where disposal to surace is ofen constrained by regulatory and environmental concerns, injectiono produced water is the principal disposal route with 89% o water being returned below ground (see Figure4.3.3).

Over the 3 years shown the proportion o water re-injected compared with water discharged has increasedoffshore and decreased onshore.


30/6422


OGP

Figure 4.3.2: Percentage of produced water re-injected offshore by region expressed as percent total produced water generated onshore

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

OverallSouth &Central America

NorthAmerica

MiddleEast


Africa

2012

2011

2010

Note: A very small amount of produced water was reported for the FSU and the Middle East both onshore and offshorecompared with the other regions.

Figure 4.3.3: Percentage of produced water re-injected onshore by region expressed as percent total produced water generated offshore

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

OverallSouth &Central America

NorthAmerica

MiddleEast


Africa

2012

2011

2010


31/6423


OGP

While much o the 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 providehigher lubricity, better perormance at higher temperatures and well-bore stability compared with water-

based muds. Tese challenges arise especially with techniques such as extended-reach and directionaldrilling, either or both o which may be required to develop new reservoirs or to improve recovery rom

previously identified resources. OGP reports non-aqueous base fluids (NABFs) according to the ollowingclassifications:

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 III Enhanced mineral oilSynthetics (esters, olefins, paraffins)


32/6424


OGP

Figure 5.1.1: Total base fluid (NABF) retained on cuttings discharged to the sea tonnes

0

3000

6000

9000

12000

15000

18000

21000

24000


NorthAmerica

MiddleEast


Africa

Unspecified

Group III

Group II

2010

2011

2012

842

30

40

16

51

128 4 2

0 0 0

12

30

17

18

12

10

30

35

24

07

29

71487

4436 1

203

69

238

76

146

88

2010

2011

2012

2010

2011

2012

2010

2011

2012

2010

2011

2012

2010

2011

2012

2010

2011

2012

Note: NABF discharges were reported by 21 of the 43 participating companies in 2012;No Group 1 NABF discharges to the sea were reported in 2008-2012.


33/6425


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 containment), irrespective o quantity recovered.

Spills may have a number o causes such as equipment ailure (including corrosion), operating errors, andunlawul third party damage such as 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 2012, companies reported a total o 7 826 oil spil ls. O these, 6 146 (79%) were spills o less than onebarrel in volume, amounting to a total o 89 tonnes o oil. Because o the small cumulative volumeinvolved and, as some companies do not report spills less than 1 barrel in size, these 1 barrel 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

OverallOffshoreOnshore

1.

33

0.

19

0.

84

2012

2011

2010

2009

2008

2007

2006

Spills


34/6426


OGP

Figure 6.1.2 shows the number o spills normalised per unit hydrocarbon production by region. Rates or2012 vary rom 0.2 spills per million tonnes o production in the Asia/Australasia to 2.1 spills per milliontonnes o production in North America.

Figure 6.1.2: Number of oil spills > 1 barrel per unit of hydrocarbon production by region spills per million tonnes

0

1

2

3

4

5

6

7

8

9

10


NorthAmerica

MiddleEast


Africa

0.1

6

0.4

8

0.4

3

0.2

6

0.3

8

9.0

1.4

5 Overall 0.84 2

.10

2012

2011

2010

Te all in the number and quantity o spills reported or South & Central America in 2012 comparedwith 2011 is due to a change in the number o companies submitting data or the region. Tis change is alsoreflected in the results or onshore spills 10100 barrels in size as well as the overall results in Figure 6.1.1.

When normalised to hydrocarbon production (see Figure 6.1.3), spill volume rates do not show any

consistent trend over the 7-year period shown. Te normalised spill volume rate reported or offshoreoperations in 2012 was less than one fifh o the onshore rate.

Figure 6.1.3: Quantity of oil spilled per unit of hydrocarbon production tonnes per million tonnes

46.

98

1.1

9

8.6

0

4.7

6

2012

2011

2010

2009

2008

2007

2006

0

5

10

15

20

OverallOffshore Onshore

46.9

8

8.6

0

4.7

6

1.1

9


35/6427


OGP

Te quantity o oil spilled per unit o hydrocarbon production in 2012, based on reports received, has allento 4.8 tonnes per mill ion tonnes o production, 40% lower than the rate or 2011 as shown in Figure 6.1.4.Te overall drop rom 2011 is mainly influenced by a reduction in the volumes o reported spills in Arica

and South & Central America as well as a change in the companies reporting in South & Central America.

Figure 6.1.4: Quantity of oil spilled (spills > 1 barrel) per unit of hydrocarbon productionby region tonnes per million tonnes

0

5

10

15

20

25


NorthAmerica

MiddleEast


Africa

2.8

40.9

7

13.7

4

0.6

7

4.3

3

0.3

6

Overall 4.76

4.2

1

2012

2011

2010

Figures 6.1.5 and 6.1.6 show the reported quantities o oil spilled per unit o hydrocarbon production,onshore and offshore respectively, in the different geographic regions. In Arica, reported spills greater than1 barrel in size amounted to 3 622 tonnes o oil onshore, 285 tonnes offshore and 1 519 tonnes where theonshore/offshore breakdown was not available.

Figure 6.1.5: Quantity of oil spilled (spills > 1 barrel) per unit of hydrocarbon production onshoreby region tonnes per million tonnes

0

5

10

15

20

25


NorthAmerica

MiddleEast


Africa

1.1

02.0

5

31.7

0

4.

46

53.1

1

32.5

55.5

3

15.2

4

1.4

0

4.8

6

Overall 8.60

2012

2011

2010

his does not include any data related to the Deepwater Horizon incident, which is the subject o on-going,multi-district litigation. his applies to Figures 6.1.4 and 6.1.6.


36/6428


OGP

Figure 6.1.6: Quantity of oil spilled (spills > 1 barrel) per unit of hydrocarbon production offshoreby region tonnes per million tonnes

0

5

10

15

20

25


NorthAmerica

MiddleEast


Africa

23.6

0.1

3

2.8

0

1.1

5

0.0

5

0.0

0

0.2

3

0.3

7

Overall 1.19

2012

2011

2010

Te higher value in 2011 or the quantity o oil spilled offshore per unit o production in Arica, as shownin Figure 6.1.6, is dominated by a single oil spill in Nigeria in which 4.8 thousand tonnes o oil were spilledduring the transer o oil rom a floating production, storage and offloading vessel to an oil tanker, 120kmoffshore.

Figure 6.1.7: Distribution of oil spills onshore and offshore by size number of spills

0

100

200

300

400

500

600

700

800

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

205

32 37 00

2710

69

139

681

140

340

Unspecified

Offshore

Onshore

Figure 6.1.7 shows the distribution o spills larger than 1 barrel in terms o number o spills in each sizecategory or 2012. In terms o number o events, the distribution is dominated by the number o spillsbetween 1 and 10 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; spills >100 barrels in size represent 77% o thetotal oil spilled.

In addition to the data shown in Figure 6.1.7, a total o 6 146 spills (3 157 onshore, 2 688 offshore, and 301unspecified location) o less than 1 barrel in size were reported by participating companies.


37/6429


OGP

pills greater than barrels in size

In 2012, 106 spills in which more than 100 barrels o oil was released (69 onshore, 10 offshore, 27 unspecifiedlocation) were reported by participating companies.

O the 106 spills, participating companies provided incident descriptions or 37 o the individual incidents.Te 4 largest o the 37 were:

628 tonnes (~4 689 barrels) o crude oil was spilled in a single sabotage/thef incident in Nigeria.

579 tonnes (~4 318 barrels) o crude oil was spilled in a single incident in Kuwait and was the result o aleaking pipeline flange due to corrosion during drilling operations. 541 tonnes o the oil was recovered.

577 tonnes (~4 304 barrels) o condensate was spilled offshore in the UK as a result o a unique

interaction o rock ormation and pipe corrosion 263 tonnes (~1 960 barrels) o crude oil leaked rom a gravity line as a result o corrosion during drilling

activities in Kuwait. 246 tonnes o the oil was successully recovered.

Figure 6.1.8: Distribution of oil spills onshore and offshore by size2012number of spills

Figure 6.1.9: Distribution of oil spills onshore and offshore by size2012quantity spilled (tonnes)

0

100

200

300

400

500

600

700

800

UnspecifiedOffshoreOnshore

205

323700

2710

69

139

681

140

340

1 < x < 10 bbl

10 < x < 100 bbl

> 100 bbl

Unspecified

0

1000

2000

3000

4000

5000

6000

UnspecifiedOffshoreOnshore

868

10118 00

10971007

5221

627292

53 194

1 < x < 10 bbl

10 < x < 100 bbl

> 100 bbl

Unspecified


38/6430


OGP

ause (excluding intentional third party damage)

A specific cause was provided or 72 spills >100 barrels in 2012. Excluding the 39 categorised as third party

damage, the cause was reported or 33 o the spills >100 barrels in size, which collectively were associatedwith 27% o the total oil spilled (2 580 tonnes). See Figure 6.1.10.

O the 3 spill incidents categorised as other in 2012, 1 was the result o a road traffic accident and 2 werecaused by lightning strikes.

ntentional third party damage (sabotage, thef, vandalism, etc)

Incidents caused by third party damage account or 39 o the spills >100 barrels in size where the cause wasreported in 2012. Tese third party spills represent 3 209 tonnes o oil, 34% o the total oil spilled.

pills between and barrels in size

Since 2010, detailed inormation has been reported or spills between 10 and 100 barrels in size.

In 2012, 376 spills in this category were reported in total (205 onshore, 32 offshore, 139 unspecified location).

Te quantity o oil recovered was reported or 71% o the 10-100 barrel spil ls; 464 (67%) o the 693 tonneso oil spil led in those incidents was reported to have been recovered.

ause (excluding intentional third party damage)

A specific cause was provided or 219 spills between 10 and 100 barrels in size in 2012. O these, 194 (79%)were related to company operations or natural causes. Collectively these operational spills or which causewas provided represent 652 tonnes o oil spilled (557 tonnes o crude oil, 51 tonnes o condensate, 19 tonneso processed oil and 26 tonnes o unspecified oil).

Figure 6.1.10 shows the distribution o cause or operational spill incidents between 10 and 100 barrels insize, where the cause was reported, or 2012.

ntentional third party damage (sabotage, thef, vandalism, etc)

Incidents caused by third party damage account or 53 (24%) o the spills 10-100 barrels in size where thecause was reported in 2012. Tese spills caused by third parties represent 279 tonnes o oil.

Other9%

Operator ortechnical error 9%

Equipment failure(excluding

corrosion) 36%

Corrosion46%

Figure 6.1.10: Operational spills >100 barrelsin sizeby cause2012

as % of spill incidents >100 barrelswhere cause was indicated excludingthird party damage

Operator ortechnical error

30%

Equipment failure

(excluding corrosion)46%

Corrosion24%

Figure 6.1.11: Operational spills 10100 barrels insizeby cause2012

of spill incidents 10-100 barrels where causewas indicated excluding third party damage


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Appendix A Data tables

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

Some o the historical results in this appendix differ rom those published in OGP report 2011e, Environmental

Perormance Indicators report 2011 data. Results affected are: 2011 Arica: some hydrocarbon production, atmospheric emissions and spill data moved rom onshore to offshorecausing an increase in offshore production, decrease in onshore production. Tis affects all 2011 results wherenormalised by production overall, onshore and offshore, and regional results or Arica only.

Aqueous discharges per unit o produced water discharged: calculation methodology changed in this analysisto exclude oil discharges where there was no produced water or the data set (previously oil was included where

produced water discharge was reported, even i the total water discharged was zero).

Georgia was moved rom Europe to FSU region. In this report the change affects gross atmospheric emissions andenergy or the two regions or the year 2011 only.

Scope of data submissions

Production associated with database and 2012 production in BP Statistical Review of World Energyby region

Region Production in this report (106t) BP Review production (106t) Production as % of BP Reviewproduction

2012

Africa 505 644 78%

Asia/Australasia 319 821 39%

Europe 381 399 96%

FSU 113 1 370 8%

Middle East 417 1 776 23%

North America 311 1 534 20%

South & Central America 187 538 35%

Total 2 233 7 080 32%

2011

Africa 387 600 64%


Europe 452 406 111%

FSU 127 1 366 9%




Total 2 221 6 950 32%

2010

Africa 405 666 61%


Europe 474 445 107%

FSU 120 1 348 9%




Total 2 268 6 795 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 are not directly comparable, but the percentage of world production figures are given as indicative of the relative regional contributionsin the database.


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No. of useable company/country data sheets/setsby region

2012 2011 2010

Region No. of datasheets No. of data sets No. of datasheets No. of data sets No. of datasheets No. of data sets

Africa 55 70 57 80 49 61

Asia/Australasia 52 71 54 70 55 68

Europe 65 85 60 77 51 68

FSU 10 11 13 14 10 11

Middle East 21 24 21 26 18 27

North America 22 32 21 30 21 33

South & Central America 27 33 28 36 24 31

Total 252 326 254 333 228 299

Data sheet: all data for one country for an individual company

Data set: a set of data with distinct company, country and location (onshore/offshore/unspecified) where there is a positive return of production, emissions,discharges, flaring, energy or spill data

Percentage of reported production included in normalised analyses

AfricaAsia/

Australasia Europe FSU Middle EastNorth

America

South &Central

America All regions

Gas emissions

CO2

99% 100% 100% 100% 55% 93% 41% 85%

CH4

79% 87% 99% 100% 55% 93% 41% 79%

NMVOC 76% 75% 99% 100% 49% 100% 35% 76%

SO2

78% 87% 100% 100% 55% 100% 35% 79%

NOX 78% 99% 100% 100% 55% 100% 35% 81%

Energy consumed 97% 100% 99% 100% 92% 94% 40% 92%

Flaring 99% 85% 99% 100% 100% 99% 39% 92%

Oil discharged in produced water 69% 95% 93% 82% 57% 76% 34% 73%

Oil spills 78% 94% 97% 100% 74% 98% 100% 89%


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. Gaseous emissions

Gas emissions per unit of hydrocarbon production (Figures 1.1, 1.2, 1.1.1.1, 1.2.1.1, 1.3.1.1, 1.4.1.1, 1.5.1.1, 1.6.1.1)

2012 2011 2010

Emission per 103tproduction

(t/103t)

Hydrocarbonproduction 106t


(t/103t)



(t/103t)


CO2

132.17 1 904 132.27 2 177 133.39 2 226

CH4

1.33 1 762 1.24 2 127 1.18 2 176

NMVOC 0.48 1 694 0.49 2 050 0.50 2 087

SO2

0.17 1 772 0.17 2 097 0.17 2 108

NOX

0.43 1 809 0.41 2 100 0.40 2 113

GHG 160.05 158.23 158.08

GHG: Total greenhouse gases (CO2+ CH4expressed in CO2equivalent: GHG = CO2+ 21 x CH4)NB Data only included where gas quantity and production level are both reported

Gross emissions of gases per region

AfricaAsia/

Australasia Europe FSU Middle EastNorth

America

South &Central

America Overall

2012

CO2(106t) 78.8 49.2 31.6 11.5 13.4 61.8 7.1 253.4

CH4(103t) 481.9 745.5 197.2 69.3 37.1 747.2 62.9 2 341.0

NMVOC (103t) 268.6 101.8 90.2 24.6 73.2 220.5 38.4 817.3

SO2(103t) 27.9 13.1 11.1 31.8 147.3 60.5 11.4 302.9

NOX(103t) 165.8 145.1 125.0 26.4 31.6 259.8 41.9 795.7

GHG (106t) 89.0 64.8 35.7 13.0 14.2 77.5 8.5 302.6

2011

CO2(106t) 79.7 64.7 34.0 13.0 17.7 53.3 26.6 289.0

CH4(103t) 565.2 861.7 185.9 72.5 58.4 648.9 237.7 2 630.3

NMVOC (103t) 305.3 196.7 98.0 22.7 87.7 180.4 120.4 1 011.1

SO2(103t) 31.6 9.5 16.3 30.5 199.2 57.0 20.4 364.5

NOX(103t) 151.0 130.9 127.0 32.6 55.6 228.6 138.5 864.2

GHG (106t) 91.6 82.8 37.9 14.5 19.0 67.0 31.6 344.2

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 1034.5SO

2(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

GHG: Total greenhouse gases (CO2+ CH4expressed in CO2equivalent: GHG = CO2+ 21 x CH4)


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Emissions per unit of hydrocarbon production (tonnes per thousand tonnes)by region (Figures 1.1.1.2 1.2.1.2, 1.3.1.2, 1.4.1.2, 1.5.1.2, 1.6.1.2)

Africa

Asia/

Australasia Europe FSU

Middle

East

North

America

South &Central

America Overall

2012

CO2emissions (t/103t) 158.00 150.53 82.63 102.13 57.87 213.61 92.91 132.17

Production (106t) 498 319 380 113 230 289 76 1 904

CH4emissions (t/103t) 1.21 2.68 0.52 0.61 0.16 2.58 0.83 1.33

Production (106t) 398 278 379 113 230 289 76 1762NMVOC emissions (t/103t) 0.70 0.42 0.24 0.22 0.35 0.71 0.59 0.48

Production (106t) 386 238 376 113 206 311 65 1694SO

2emissions (t/103t) 0.07 0.04 0.03 0.28 0.64 0.19 0.17 0.17

Production (106t) 394 279 380 113 229 311 66 1 772

NOXemissions (t/103

t) 0.41 0.43 0.33 0.23 0.13 0.83 0.62 0.43Production (106t) 394 316 380 113 230 311 66 1 809

GHG emissions (t/103t) 183.40 206.87 93.57 115.02 61.25 267.88 110.28 160.05

2011

CO2emissions (t/103t) 205.78 183.53 74.95 99.95 47.48 180.57 136.11 132.27

Production (106t) 387 351 452 127 371 295 194 2 177

CH4emissions (t/103t) 1.46 2.81 0.41 0.59 0.16 2.20 1.22 1.24

Production (106t) 387 307 451 123 371 295 194 2 127

NMVOC emissions (t/103t) 0.82 0.72 0.22 0.18 0.25 0.61 0.62 0.49

Production (106t) 372 274 448 122 347 295 193 2 050

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

Production (106t) 382 277 452 126 371 295 194 2 097

NOXemissions (t/103t) 0.39 0.47 0.28 0.24 0.15 0.77 0.71 0.41

Production (106t) 382 280 452 126 371 295 194 2 100

GHG emissions (t/103t) 236.49 242.51 83.61 112.30 50.76 226.72 161.80 158.23

2010

CO2emissions (t/103t) 205.98 1,77.24 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

NMVOC emissions (t/103t) 0.81 0.71 0.27 0.06 0.25 0.59 0.57 0.50

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

GHG: Total greenhouse gases (CO2+ CH4expressed in CO2equivalent: GHG = CO2+ 21 x CH4)NB Data only included where gas quantity and production level are both reported


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Gas emissions by source (Figures 1.1.2.1, 1.2.2.1, 1.3.2.1, 1.4.2.1, 1.5.2.1, 1.6.2.1)

Energy Flare Fugitive losses Vents Other/unspecifiedE&P

Overall

2012

CO2(106t) 91.08 48.62 0.03 8.94 104.74 253.41

CH4(103t) 45.46 197.28 271.89 322.02 1 504.37 2 341.02

NMVOC (103t) 16.74 123.93 65.64 184.79 426.20 817.30

SO2(103t) 46.53 90.72 0.00 5.79 159.86 302.91

NOX(103t) 342.10 21.97 0.00 0.19 431.42 795.67

GHG (106t) 92.04 52.76 5.74 15.70 136.33 302.57

2011

CO2(106t) 92.07 57.07 0.03 8.09 131.72 288.98

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

NMVOC (103

t) 15.84 138.42 76.02 197.36 583.50 1 011.13SO

2(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 17.81 157.05 344.22

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 (103t) 19.43 183.50 55.27 153.21 623.13 1 034.53

SO2(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

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

CO2 CH4 NMVOC SO2 NOX GHG

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

2012

Emissions (t/103t) 116.93 134.15 1.48 0.77 0.61 0.45 0.30 0.12 0.52 0.37 143.22 149.78

Production (106t) 669 975 565 937 546 922 575 971 579 971 669 975

2011

Emissions (t/103t) 142.73 126.50 1.52 1.12 0.65 0.45 0.32 0.10 0.52 0.35 174.48 149.12

Production (106t) 745 1 230 740 1 185 709 1 139 739 1 156 742 1 156 745 1 230

2010

Emissions (t/103t) 134 125.00 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

NB Data only included where gas quantities in production activities and production levels are both reported GHG: Total greenhouse gases (CO

2+ CH

4expressed in CO

2equivalent: GHG = CO

2+ 21 x CH

4)


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. Energy Consumption

Energy consumption per unit of hydrocarbon production (Figure 2.1, 2.2)

2012 2011 2010 2009 2008

% Onsite combustion 76 81 80 80 79

% Purchased 5 5 5 5 4

% Unspecified 19 16 16 16 17

Total energy consumption (GJ/t) 1.40 1.54 1.47 1.48 1.40

Production (106t) 2 047 2 024 2 092 2 151 2 049

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

Gross energy consumption (million GigaJoule)by region

Onsite Purchased Unspecified Total

2012

Africa 382.05 19.74 91.68 493.47

Asia/Australasia 362.11 10.06 237.12 609.29

Europe 422.47 38.75 7.24 468.46

FSU 88.67 0.74 41.99 131.39

Middle East 40.55 27.48 25.39 93.41

North America 822.36 54.94 112.18 989.48

South & Central America 85.68 0.55 8.17 94.40

2011

Africa 355.47 16.24 88.52 460.24

Asia/Australasia 398.98 9.08 192.89 600.95Europe 468.41 30.20 7.82 506.43

FSU 96.62 0.92 43.82 141.35

Middle East 154.33 12.06 15.96 182.35

North America 729.34 54.35 116.22 899.91


2010

Africa 366.88 15.14 84.64 466.66

Asia/Australasia 360.04 9.67 190.24 559.94

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



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Energy consumption per unit of hydrocarbon production (GigaJoules per tonne)by region (Figure 2.3)

Africa

Asia/

Australasia Europe FSU

Middle

East

North

America

South &Central

America Overall

2012

% Onsite combustion 77.4 59.2 90.2 67.5 42.4 83.1 90.7 76.5

% Purchased 4.0 1.7 8.3 0.6 29.9 5.6 0.6 5.3

% Unspecified 18.6 39.2 1.6 32.0 27.7 11.3 8.7 18.3

Total energy consumption (GJ/t) 1.01 1.90 1.24 1.16 0.24 3.39 1.25 1.40

Production (106t) 490 319 376 113 383 292 75 2 047

2011


% Purchased 3.5 1.5 6.0 0.7 6.6 6.0 3.1 4.3

% Unspecified 19.3 32.1 1.6 32.1 8.8 12.9 3.5 15.3


Production (106t) 387 350 444 123 233 294 194 20242010


% Purchased 3.3 1.7 5.4 1.2 7.7 8.0 2.8 4.8

% Unspecified 18.2 34.1 1.6 31.6 15.5 13.0 2.6 15.4


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

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 offshore

Documents

2012 Environmental OGP