The Norwegian Oil and Gas Association: Environmental Report 2013

2013

environmenTal reporT The environmenTal efforTs of The oil and gas indusTry with facts and figures

1

foreword

04

2

summary

06

3

level of acTiviTy on The ncs

4

discharges To The sea

4.1 4.2 4.3 4.4 4.5

Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 Produced water. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14 Chemicals . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 Discharges of oil . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 Acute spills. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20

5

offshore operaTions and The marine environmenT

5.1 5.2

Water-column monitoring . . . . . . . . . . . . 24 Sediment monitoring. . . . . . . . . . . . . . . . . . . . . . . 25

6

emissions To The air

6.1 6.2 6.3 6.4 6.5

08

12

22

26

Emission sources. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27 Emissions of greenhouse gases . . . . . 28 Short-lived climate forcers . . . . . . . . . . . 29 Emissions of CO2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30 Greenhouse gas emissions . . . . . . . . . . . . . . . . . from Norwegian and international . . . petroleum operations . . . . . . . . . . . . . . . . . . . . . 32 6.6 Power from shore . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 34 6.7 Emissions of NO x . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35 6.8 The NO x agreement and . . . . . . . . . . . . . . . . . . . . . . . international obligations . . . . . . . . . . . . . . . 36 6.9 Emissions of nmVOC . . . . . . . . . . . . . . . . . . . . . . . . 37 6.10 Emissions of CH4 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38 6.11 Emissions of SO x . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 39

7

wasTe

40

8

Tables

44

9 2

Terms and abbreviaTions

66

The norwegian oil and gas association (formerly the Norwegian Oil industry Association) is an interest organisation and employer’s association for oil and supplier companies related to exploration for and production of oil and gas on the Norwegian continental shelf (NCS). Norwegian Oil and Gas represents just over 100 member companies, and is a national association in the Confederation of Norwegian Enterprise (NHO).

Environmental report The environmental efforts of the oil and gas industry with facts and figures

1

Foreword A separate environmental report is published by the Norwegian Oil and Gas Association every year.

This includes emission/discharge data and provides information on the industry’s efforts and results in the environmental field.

The ambition of the petroleum industry on the NCS is to be a world leader for environmental protection, and to achieve ever better environmental results.

That makes detailed reporting of emissions/discharges important, not least in order to measure trends and the attainment of the targets set.

Emission/discharge reporting by the operator companies complies with government requirements specified in the activities regulations, and set out in detail in the guidelines from the Norwegian Climate and Pollution Agency (Klif) for reporting from offshore petroleum activities (TA-3010/2013). These require the operators to report annually in detail on emissions/ discharges from their operations on the NCS – both planned and officially approved operational and accidental emissions/discharges.

Data on emissions/discharges are recorded continuously in Environment Web, a joint database for Norwegian Oil and Gas, Klif and the Norwegian Petroleum Directorate (NPD).

Based on information from Environment Web, the Norwegian Oil and Gas environmental

report provides an updated overview of repor­ ting in 2012 on emissions to the air and discharges to the sea as well as waste generation from NCS operations. The report also contains data and research results from long-term projects related to the marine environment and environmental monitoring.

All fields with production facilities on the NCS are included. Emissions/discharges from the construction and installation phase, maritime support services and helicopter traffic are excluded.

This English version is a translation of the Norwegian report. An electronic version and detailed emission/discharge data from each field on the NCS are published on the Norwegian Oil and Gas website.

5

2

Summary Greenhouse gas emissions from oil and gas activities are relatively stable, but substantially lower than the forecasts prepared a few years ago.

Norway’s offshore industry tops the world table for recovery factors.

At the same time, a number of Norwegian fields are entering a mature phase and the proportion of gas in NCS output is increasing. Production is thereby becoming more energy-intensive. Nevertheless, carbon emissions per unit produced are being kept at a very low level compared with global figures.

Good progress with discoveries and persistently strong energy prices have laid the basis for a high level of activity on the NCS in recent years. The investment outlook in the petroleum industry is also promising for the next few years. New discoveries are to be developed, and a number of the older producing fields on the NCS are currently undergoing major upgrades.

For the first time since 2008, overall production from the NCS increased from the year before. A continued decline in oil output was offset by record gas sales.

Against the background of new discoveries, overall petroleum production is again expected to be able to rise somewhat over the next few years. Gas output has exceeded oil production since 2010, and is expected to account for about 50 per cent of petroleum sales from the NCS over the coming five-year period.

Figures for 2012 show that carbon emissions were stable, while the volume of NOx released declined slightly. The oil and gas industry is a major contributor to the environmental agreement on NOx, which regulates the commitments made to the government by Norway’s industry associations on reducing their overall NOx emissions. The fund model established

99.8% reduction in red and black chemicals

by this deal ensures that emission reductions are implemented where they yield the biggest environmental gain per krone spent. Commitments in both first and second agreement periods have so far been met. A positive additional effect is that emissions of carbon equivalent will also be reduced by 370 000 tonnes per annum, calculated from 2015, because of the nitrogen oxide projects implemented.

Emissions of non-methane volatile organic compounds (nmVOC) stabilised from the year before, but have been reduced by almost 88 per cent since 2001. These substantial cuts have been achieved through investment in new facilities for removing and recovering oil vapour on storage ships and shuttle tankers. Methane emissions from installations have also declined.

The petroleum industry has made substantial efforts to prevent discharges to the sea.

So it is positive that these have been reduced to a very low level for environmentally hazardous chemicals. Norway’s environmental authorities concluded in 2006 that the industry had reached the target of zero hazardous discharges for chemical additives set in 1997. Such discharges have now stabilised at this low level. The decline in acute discharges seen over the past five

410

NOK

per tonne – carbon tax for the petroleum industry from 2013

years is also continuing. That applies to both the volume spilt and the number of spills.

Discharges of treated produced water are stable. They are not increasing despite aging fields and an increased scale of injection to improve oil recovery, and lie considerably below forecasts from the NPD. The oil content in produced water is 60-70 per cent below the discharge threshold set by the environmental authorities, both nationally and internationally.

The oil and gas industry carefully monitors the marine environment to investigate the possible effects of its discharges to the sea.

This environmental monitoring has been conducted by independent scientists since the 1970s and is assessed by the government’s panel of experts. The results provide a unique and extensive body of material open to research and more detailed analyses.

Findings over the past 15 years show that the industry’s activities have no effect on Nature’s capacity for production and selfrenewal beyond the immediate vicinity.

The conclusion is that Norway continues to have the world’s cleanest petroleum production when account is taken of its high recovery factor and its environmental efficiency in using both chemicals and energy.

370 000 tonnes in reduced annual emissions of carbon equivalent from 2015 as a result of NOx projects

7

3

Level of activity on the NCS The oil and gas industry has completed another year with a high level of activity on the NCS.

Good progress with discoveries and persistently strong energy prices have laid the basis for a high level of activity on the NCS in recent years. Falling production curves are flattening out.

This development has taken place at a time when Norway’s traditional export industries have been hit by the international recession. The outlook for activity in the petroleum sector is also promising over the next few years. However, the industry must overcome the challenges of keeping down the growth in costs.

The oil and gas industry has completed another year with a high level of activity on the NCS. Energy prices remained high despite ever weaker trends in the world economy. Substantial optimism prevails in the industry. The investment outlook points to a persistently high level of activity over the next few years. New discoveries are to be developed, and a number of the older producing fields on the NCS are currently undergoing major upgrades.

A high level of activity bears the seeds of cost growth and reduced competitiveness.

At a time when large parts of Norwegian industry exposed to competition are exper­ iencing weak market prospects for their products, it is important that the petroleum sector contributes to keeping costs down.

Overall output flattening out

Production from the NCS totalled 226 million standard cubic metres of oil equivalent (scm oe) in 2012, up by 6.3 million scm oe (2.9 per cent) from the year before.

This is the first time since 2008 that output rose from the previous year. According to the NPD, overall production should remain at roughly the 2012 level for the next five years.

Oil: 1.5 million b/d

However, oil production continued to decline to 89.2 million scm, or a daily average of just over 1.5 million barrels. That was 8.3 million scm or 8.5 per cent down from the year before. The NPD’s five-year forecast predicts a further decline in 2013, followed by a possible slight rise.

Average daily output in 2017 is estimated to be 1.6 million barrels, down by almost 50 per cent from the 2000-01 peak.

Gas: half of future petroleum sales

Resource base upgraded

The decline in oil production during 2012 was more than offset by record gas sales.

Gas output in 2012 came to 114.6 billion scm, up by 13.2 billion scm or 13 per cent from the year before. Norway increased its share of a weak European gas market.

After strong growth since the start of the previous decade, gas production exceeded oil output in 2010 and will account for about 50 per cent of petroleum sales from the NCS in the next five-year period.

The NPD conducted a review of undiscovered resources during 2012 which – combined with new discoveries and reassessments of earlier assessments – increased the overall estimate of resource on the NCS from 13.1 billion scm oe to 13.6 billion. This figure includes oil and gas which has been sold and delivered. The resource estimates cover the same geographical area as the analyses conducted in 2010 and earlier. That excludes the Norwegian share of the former area of overlapping claims in the south-east Barents Sea as well as the waters around Jan Mayen. An updated resource estimate was also presented by the NPD for these areas in February 2013, which helped to boost estimated undiscovered resources on the NCS by roughly 15 per cent. That corresponds to roughly 390 million scm oe.

Condensate production totalled 4.5 million scm in 2012, on a par with the year before.

This figure is expected to decline gradually over the next five years. NGL production totalled 17.7 million scm, compared with 16.3 million in 2011, and has more than doubled since 2000. The NPD expects a further increase to just over 20 million scm in 2017.

Exploration high, finding rate good

The level of exploration activity on the NCS has been high in recent years. Forty-two exploration wells were spudded during 2012, and 41 completed. The wells spudded included 26 wildcats and 16 for appraisal.

Exploration activity in 2012 contributed to 13 new discoveries, which represented a finding rate of 50 per cent. Five of the finds were in the North Sea, five in the Norwegian Sea and three in the Barents Sea. Resources in these new discoveries are estimated at 132 million scm oe, corresponding to 58 per cent of 2012 output. Viewed as a whole, new discoveries during the past five years corresponded to no less than 79 per cent of production in the same period.

Activity high on the NCS

According to investment figures for the petroleum sector from Statistics Norway, NOK 172.5 billion was invested in 2012 – up by NOK 26.2 billion from the year before.

The 2012 increase related to field developments and producing fields, while exploration, land-based operations and pipeline transport showed a decline. Investment figures for the first quarter of 2013 indicate a continued high level of activity on the NCS. The oil companies expect overall capital spending for the year to be NOK 198.7 billion. Field developments, producing fields and exploration activities will continue to make the principal contributions to boosting investment in 2013. The petroleum sector thereby confirms its role as the most important engine driving the Norwegian economy.

9

New acreage still important

The government announced the 22nd offshore licensing round on 26 June 2012, offering 86 full or part blocks in the Barents (72) and Norwegian (14) Seas. Advance nominations covering 228 full or part blocks had been received by the Ministry of Petroleum and Energy from the companies, of which 107 received two or nominations. A record 181 blocks were nominated for the Barents Sea. At the deadline of 4 December 2012, the ministry had received applications from 36 companies.

On 15 February 2013, the ministry announced the annual round for the awards in predefined areas (APA) covering mature regions of the NCS. The predefined area has been enlarged with six blocks.

All lie in the Norwegian Sea close to Aasta Hansteen, and are based on the management plan for this part of the NCS. The deadline for applications is 11 September 2013, and plans call for new licences to be

Figure

Figure

01

It aims to award new licences before the summer vacation in 2013.

Petroleum production by region Million scm oe

02

awarded in early 2014. The APA scheme contributes to a high and stable level of activity on the NCS, and its enlargement must be viewed as positive. At the same time, Norwegian Oil and Gas believes that the APA must be enlarged annually in order to include all areas close to discoveries – including those currently non-commercial – and all areas where geological understanding is so good that awards can be made with a simpler procedure and without regional interpretations.

Investment in the oil sector by category (NOK bn)

Source: NPD

300

Source: Statistics Norway

200

180 Estimate for 2013 from Statistics Norway’s investment survey for the oil industry, first quarter 2013.

250 160

140 200 120

150

100

80 100 60

40 50 20

0

0 1973 North Sea

10

1981

1989 Norwegian Sea

1997 Barents Sea

2005

2013

1985

1989

1993

1997

2001

2005

2009

Field development

Producing fields

Land-based operations

Exploration and conceptual studies

2013

Pipeline transport

Figure

03

NCS resource growth and production Million scm oe Source: NPD

450

400

350

300

250

200

150

100

50

0 1990

1991

1992 1993

Resource growth

1994

1995

1996

1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010

2011

2012

Overall petroleum production

11

4

Discharges to the sea Both operational and acute discharges to the sea from oil and gas operations on the NCS are declining.

4.1 Drilling Generally speaking, operational discharges to the sea are on the way down. That includes discharges of produced water, contrary to forecasts predicting the opposite. However, greater exploration activity means that more drilling waste is being sent ashore for final treatment, and that discharges of water-based drill cuttings have risen. Both the number of acute oil spills and the total volume discharged in such incidents are falling.

Drilling operations generate two types of waste – drill cuttings, which are rock drilled from the well, and used drilling fluids.

The fluid has many functions, including bringing up drill cuttings, lubricating and cooling the drill bit, preventing the borehole from collapsing and keeping pressure in the well under control. Drill cuttings will always be contaminated with used fluid.

The industry currently utilises two types of drilling fluids: oil- and water-based.

Ether-, ester- or olefin-based synthetic fluids were also utilised earlier, but have been little used in recent years.

Discharging oil-based or synthetic drilling fluids, or cuttings contaminated with these, is prohibited if the oil concentration exceeds one per cent by weight – in other words, 10 grams of oil per kilogram of cuttings.

About 23 000 tonnes of drill cuttings contaminated with oil-based drilling fluids were injected in 2012, up by 18 per cent compared with the year before. Problems with certain injection wells in recent years mean that the proportion of injected cuttings has declined markedly. A number of measures have been launched to avoid similar problems in the future, and new injection wells have been taken into use.

Water-based drilling fluids usually contain natural components, such as clay or salts.

Such components of fluids will be listed as green chemicals in the classification system

Injection of drill cuttings contaminated with oil-based drilling fluids (tonnes)

60 000

Figure

Figure

04

Used oil-based drilling fluids and cuttings are either shipped ashore for acceptable treatment or injected in dedicated wells beneath the seabed.

05

applied by Klif. Green substances pose little or no risk to the marine environment and are on Ospar’s Plonor list. The government permits the discharge of used water-based fluids and drill cuttings upon application.

The impact of these discharges is tracked through extensive environmental monitoring. Since 2011, the discharge regime for drill cuttings and drilling fluids has been the same for the whole NCS. Special requirements can be imposed if required.

Discharges of water-based drill cuttings rose substantially in 2008-10 because of increased exploration activity on the NCS. They totalled about 172 000 tonnes in 2012, which means that the decline from the peak year of 2010 continued.

Injection of drill cuttings when drilling with water-based fluids (tonnes)

250 000

50 000

200 000

40 000 150 000 30 000 100 000 20 000 50 000

10 000

0

0 2004

2005

2006

2007

2008

2009

2010

2011

2012

2004

2005

2006

2007

2008

2009

2010

2011

2012

13

4.2 Produced water Produced water has been in contact with the geological formations for millions of years, and accompanies oil up to the platform for separation and treatment before being discharged.

About 131 million cubic metres of produced water were discharged on the NCS in 2012, up by two million cubic metres from the year before (figure 06). Discharges fell markedly from 2007 to 2009, and have subsequently lain around 130 million cubic metres per year.

Almost 33 million cubic metres of produced water, corresponding to some 20 per cent of total water production, were injected in 2012. The proportion of produced water injected fell briefly in 2007, but has since lain around 30 million cubic metres per year.

Figure

06

The average oil concentration in produced water discharges was 11.7 milligrams per litre in 2012. That was far below the official ceiling of 30 milligrams per litre. The trend for the concentration of dispersed oil is presented in figure 07.

Discharges and injection of produced water (million cubic metres)

Discharges of produced water normally rise with the age of a field, because the ratio of water to oil in the wellstream – the water cut – steadily increases. Water injection, used to maintain reservoir pressure and boost oil recovery, can also contribute to a higher volume of produced water.

The industry is working continuously to reduce discharges. According to ongoing environmental monitoring, no environmental impact can be identified from discharging produced water.

200

180

160

140

120

100

80

60

40

20

0 2003

2004

2005

Produced water discharged

14

A total of 1 535 tonnes of dispersed oil was discharged to the sea in 2012, up by 3.9 per cent from the year before.

2006

2007

2008

Produced water injected

2009

2010

2011

2012

Figure

Figure

07

Average oil concentration in produced water (mg/l)

35

08

Ratio between produced water and oil

2.0 1.8

30

1.6 25

1.4 1.2

20

1.0 15

0.8 0.6

10

0.4 5

0.2

0

0 2003

2004

2005

2006

Regulatory requirement

2007

2008

2009

2010

2011

Concentration (mg/l) of dispersed oil in produced water

2012

2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

Produced water/oil

15

4.3 Chemicals Chemicals are assessed on the basis of their environmental properties.

Today’s criteria are specified by the government in the guidelines for reporting from offshore petroleum operations (Klif, TA-3010, table 01).

A dedicated flow diagram has been developed for environmentally hazardous substances to determine the category they should be reported in. As a general rule of thumb, chemical additives are divided

by Klif into four categories in accordance with the classification in chapter 10 of the activities regulations:

1) Green Chemicals considered to have no or very limited environmental impact.

Can be discharged without special conditions.

2) Yellow Chemicals in use, but not covered by any of the other categories.

Can normally be discharged without specified conditions.

Figure

09

3) Red Chemicals which are environmentally hazardous and should therefore be replaced. Can be discharged with the permission of the government, but must be given priority for substitution.

4) Black Chemicals which are basically prohibited for discharge. Permits are issued only in special circumstance – where it is crucial for safety, for instance.

Discharges of chemical additives totalled 160 162 tonnes in 2012. Green chemicals accounted for 91.5 per cent of this, yellow for about 8.4 per cent, and red and black for 0.005 and 0.0016 per cent respectively.

See figure 09. Roughly 48 000 tonnes of chemicals were injected below ground.

Chemical discharges broken down

by Klif’s colour coding (2012)

Yellow

8.5% Green

16

91.5%

Black Red

0.0016 % 0.0047%

The operators have worked purposefully to replace chemicals which have poor environmental properties with more environmentally acceptable alternatives. This means that over 99.8 per cent of the chemicals in the red and black categories have been phased out. Discharges of black chemicals, for instance, fell from 228 tonnes in 1997 to 2.4 tonnes in 2012. Black chemical discharges were slightly higher in 2012 than the year before because of tests with fireextinguishing chemicals on a new offshore installation. Work on replacing these is under way. Correspondingly, red chemicals fell from almost 4 000 tonnes to 7.5 tonnes.

Ever since 2006-07, the government has considered the zero discharge goal for chemical additives to have been reached. Klif assessed zero discharge work most recently in 2010.

The industry is considering various measures which could help to reduce environmental risk, in part through the Ospar-OIC and a riskbased approach (RBA) to naturally occurring chemicals. The RBA aims to describe the risk related to discharging various substances which occur naturally.

Colour-coding of chemicals has existed for more than a decade. Progress in substituting chemical additives over the period presented in figure 10 makes it difficult to envisage substantial reductions for red and black chemicals in coming years. So it will also be important to utilise environmental monitoring as a tool for assessing the extent to which discharges represent significant pollution of the environment. The industry’s goal is zero environmental harm as a result of petroleum operations, and its monitoring documents that discharges do not damage nature’s capacity for production and selfrenewal.

table

01

klif’s table

Discharge

Category1

Klif’s colour category

Discharge

Water

Category1

Klif’s colour category

Substances in yellow category:

Substances on Ospar’s Plonor list

Green

Substances covered by Reach annexes IV and V 6

99

Yellow

Substances with biodegradability > 60%

100

Yellow

Substances with no test data

0

Black

Hormone disruptors 2

1

Black

1.1

Black

Sub-category 1: expected to biodegrade fully

101

Yellow

Sub-category 2: expected to biodegrade to environmentally non-hazardous substances

102

Yellow

Sub-category 3: expected to biodegrade to substances which could be environmentally hazardous

102

Yellow

Substances thought to be, or which are, hazardous to genes or reproduction 3 List of prioritised substances in result objective 1 (priority list), proposition no 1 (2009-2010) to the Storting

2

Black

Biodegradability < 20% and log Pow ≥ 5 4(4)

3

Black

Biodegradability < 20% and toxicity EC50 or LC50 ≤ 10 mg/l

4

Black

Chemicals on Ospar’s taint list 5

5

Red

Two out of three categories: biodegradability < 60%, log Pow ≥ 3, EC50 or LC50 ≤ 10 mg/l 4

6

Red

Inorganic and EC50 or LC50 ≤ 1 mg/l

7

Red

Biodegradability < 20% 4

8

Red

Substances with biodegradability 20-60%

A description of the category is provided in the flow diagram.

Category in table 5-1 has been related to category in table 6-1 to ensure correspondence with reported figures in the two tables.

1

Figure

10

Removed from the black category in the activities regulations.

2

3

Substances hazardous to genes or reproduction are understood to mean mutagen categories (Mut) 1 and 2 and reproduction categories (Rep) 1 and 2, see appendix 1 to the regulations on labelling, etc, of hazardous chemicals or self-classification.

5

Removed from the red category in the activities regulations.

6

Commission regulation 987/2008. Klif must assess whether the substance is covered by annex V.

4 Data for degradability and bio accumulation must accord with approved tests for offshore chemicals.

Historical development of green, yellow, red and black chemical discharges (tonnes) 16 000

160 000

700

5

600 4 12 000

120 000

500 3

400 8 000

80 000

300

200

4 000

40 000

2

1 100

0

0 03 04 05 06 07 08 09 10 11 12

Green chemicals

0 03 04 05 06 07 08 09 10 11 12

Yellow chemicals

0 03 04 05 06 07 08 09 10 11 12

Red chemicals

03 04 05 06 07 08 09 10 11 12

Black chemicals

17

18

4.4 Discharges of oil Operational discharges of oily water from petroleum activities on the NCS have three principal sources.

â&#x2013; Produced water: water which has been

â&#x2013; Displacement water: seawater used

in the storage cells for crude oil on some platforms. This has a small contact area with the crude and a relatively low content of dispersed oil. Discharge volumes depend on the level of oil output.

â&#x2013; Drain water: rain and wash water

from the platform decks which could contain chemical residues. Discharges of drain water represent a small part of the total volume of water released to the sea.

Water-jetting also occurs. Oily sand and impurities accumulate in separators and must be flushed out from time to time by such jetting. Some oil contamination remains on the particles after the water has been treated. The amount of oil released to the sea from water jetting is marginal.

Oil discharges can also occur in wash water used to clean process equipment, in connection with accidents or from deposition of oil droplets released by flaring in connection with well testing and workovers.

Figure

in contact with the geological formations for millions of years, and which accompanies the oil up to the platform.

It contains various inorganic salts, heavy metals and organic substances.

Small proportions of the salts give off low-level radioactivity. Although the produced water is treated before discharge, it will contain minor residues of oil/condensate as well as dissolved substances.

11

Total discharges of oil to the sea from produced, displacement, drain and jetting water totalled 1 645 tonnes in 2012, compared with 1 589 the year before. Dispersed oil in produced water discharges represented the largest volume, at 1 535 tonnes in 2012.

Historical development of oil discharges to the sea from various sources (tonnes)

6 000 The marked peak in 2007 reflects the acute spill of about 4 700 scm from the Statfjord loading buoy.

5 000

4 000

3 000

2 000

1 000

0 2003

2004

Dispersed oil in produced water

2005

2006

2007

Displacement, drain and jetting water

2008

2009

2010

2011

2012

Acute spills

19

4.5 Acute spills Acute spills are defined as unplanned emissions/discharges which occur suddenly and are not covered by a permit. Possible environmental consequences of such releases will depend on the environmental properties and volume of the substance emitted/spilt, and when and where the incident occurs. Norway’s oil and gas industry pays great attention to adopting measures to prevent incidents which could lead to acute emissions/discharges.

These are classified in three principal categories: ■ oil: diesel, heating, crude, waste and others ■ chemicals and drilling fluids ■ acute emissions to the air.

Oil spills in 2012 involved 122 incidents, of which only four were larger than a cubic metre and 26 were above 50 litres. The total volume of oil from all acute spills during the year was 16 cubic metres.

The number of acute oil spills on the NCS increased somewhat in 2004-08, reflecting a rise in incidents smaller than 50 litres.

A steady fall in the total number has taken place since 2008. A clear declining trend

The Kristin platform.

20

is evident for spills larger than 50 litres from as far back as 1997.

Acute spills of chemicals have been stable at 100-140 incidents over the past decade, but rose to 162 in 2009. That has been followed by a steady decline, to 148 in 2012.

The overall volume of all types of acute discharge to the sea on the NCS was 381 cubic metres in 2012.

Large acute chemical spills in 2007, 2009 and 2010 came from injection wells.

Injection has been used to reduce discharges from oil and gas production on the NCS for several decades. It offers substantial environmental gains and can be cost-effective

compared with transport to land and deposition at approved waste treatment facilities, for example. However, a number of leaks from injection wells have been discovered, particularly in 2006-09.

The volume involved was calculated on the basis of assumptions that the wells had been leaking for many years, while the volume was specified for a single year. A full review of all fields which utilise injection was therefore conducted, and a number of measures instituted. Discharges from injection wells have now ceased. Improved preliminary investigations of the sub-surface and other measures adopted mean that the proportion of injected waste is likely to rise again in coming years.

Figure

Figure

12

Total acute oil spills on the NCS

14

Total volume of acute spills broken down by oil and chemicals (cu.m) Chemicals are mainly drill cuttings.

14 000

200

150 12 000 100

50

10 000

0 2003

2004

2005

2006

2007

2008

2009

2010

2011

2012 8 000

Total exceeding 50 litres

Figure

13

Total acute spills

Acute chemical spills on the NCS

6 000

180 160 140

4 000

120 100 80 2 000 60 40 20 0

0 2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 Chemicals

Oil

21

5

Offshore operations and the marine environment Environmental monitoring involves the systematic collection of data using verifiable methods.

The goal is to document the condition of the marine environment and its development.

The oil and gas industry carefully monitors the marine environment in order to investigate the possible effects of its activities and discharges to the sea.

Monitoring of sediments has been under way since the 1970s, and its results are collected in a detailed database which contains a unique body of material open to research and more detailed analyses.

Monitoring is conducted by independent and qualified consultants in accordance with government requirements and standards. It involves the systematic collection of data using verifiable methods, where possible on the basis of a hypothesis about the possible impact of the discharges. This work consists today of sediment and water monitoring in addition to specific studies in areas with such features as coral reefs.

Environmental monitoring aims to document the condition of the marine environment and its development as a consequence both of human impacts and of natural changes. Considerable research is also being conducted by individual companies and the petroleum sector as a whole to develop monitoring methodologies and an understanding of the impact of industry discharges on the marine environment.

In addition comes substantial work on developing methods and procedures for preliminary studies in order to avoid physical damage to such features as coral reefs and sponge colonies. The scientists have concluded that no damage to coral reefs has ever been identified as a result of petroleum operations on the NCS. This work is now being extended to cover sponge colonies and various sponge species.

Research programme

The research programme on long-term effects of discharges to the sea from petroleum-related activities (2002-15) (Proof and Proofny) in the Oceans and Coastal Areas programme at the Research Council of Norway has contributed much new knowledge about the significance of discharges from offshore petroleum operations. Sixtyfive projects have been implemented so far.

A common denominator for surveys of biological responses is that these have only been identified in concentrations of produced water of 0.1 to one per cent – in other words, in the immediate vicinity of the discharge site.

Extremely sensitive methods also make use of biomarkers, which can reveal whether organisms have been exposed to discharges.

However, no link has been established between detection in a biomarker and effects on individuals or populations.

Proofny has concluded that exposure to alkylphenols from produced water on the NCS is too low to cause reproductive effects of any significance in fish stocks.

Other conclusions include the following:

■ Environmental monitoring results have

reduced concerns about the effect of oilpolluted waste deposited in earlier periods.

■ The studies show that effects on indica-

tors for health, function and reproductive ability can be demonstrated in laboratories for individual fish and invertebrates when using higher concentrations of components in produced water and/or when exposure time is unrealistically long (months) compared with natural conditions offshore, where exposure will be limited to a matter of hours.

The industry will continue to support Proofny until the programme concludes at the end of 2015. Plans are being drawn up by the Research Council for a new programme of environmental and marine research called Promamil in order to maintain the scientific effort for coastal and sea areas. That includes the petroleum sector.

Norwegian Oil and Gas will consider how it can contribute to this work.

■ Nothing suggests that Arctic and sub-

Arctic marine organisms are more vulnerable to discharges than similar life forms found elsewhere on the NCS.

23

5.1 Water-column monitoring Monitoring the water column has been under way since the late 1990s, and covers both impact and condition. This work is conducted in a way which allows the risk of impacts to the pelagic environment as a result of discharges from petroleum operations to be verified.

The scope of the monitoring must be proportionate to the expected risk.

Impact monitoring

Monitoring of impacts is conducted every year and will as a minimum embrace fish and mussels. Since 2003, these studies have primarily utilised organisms in cages (mussels and fish) with the use of biomarkers and/ or passive sampling (which accumulates organic environmental toxins).

This work was done during 2012 on the Troll field in the North Sea with the aid of underwater rigs containing mussels and passive sampling devices at increasing distances from the discharge site – more specifically 500, 1 000 and 2 000 metres, with reference stations 50 kilometres away.

A total of 13 stations were positioned for about six weeks. Current meters and conductivity, temperature and depth (CDT) sondes were also installed.

An enhanced level of certain oil components was identified in mussels 500 metres from the discharge point compared with the station 1 000 metres away. The levels were comparable with the 2011 survey on Gullfaks C, but higher than those on Ekofisk in 2006, 2008 and 2009. Mussels positioned 1 000 and 2 000 metres away had values at the background level for the North Sea. This confirms earlier findings

24

that discharges are rapidly diluted to the background level. Effects can be detected where the concentration is above about one per cent, usually 500-1 000 metres from the discharge.

Biomarker levels were moderately higher at the closest stations and declined with increasing distance, in line with earlier impact monitoring results. The investigation concluded that biological effects were not observed in mussels around the platform.

Monitoring of naturally occurring 226Ra in mussels yielded results at the background level, which indicates that no bioaccumulation occurs in these organisms.

Condition monitoring

Such surveys are conducted with fish at triennial intervals, most recently in 2011.

Findings include: ■ As before, levels of oil components

(NPD and PAH) in cod and haddock muscle were below the detection limit for the analysis.

■ The sum of PAH (EPA16) in haddock livers was higher in the reference area

on the Egersund Bank (32 ng/g) than in the Tampen area. This could indicate that PAH levels are relatively low on Tampen, where oil industry discharges are present.

■ No elevated levels of bile metabolites in haddock on Tampen, compared with the Egersund Bank.

■ The DNA adduct level in haddock varied from about five times 10-9 nucleotides on the Egersund Bank to seven times 10-9 nucleotides on Tampen. This level is lower than the one reported from a data set in 2002 (20 adducts times 10-9 nucleotides).

■ No differences in the liver somatic index, LSI or PAH metabolite levels in bile from fish on Tampen and in the reference area.

These results show that oil and gas activities in the area do not affect food safety aspects of the fish species investigated. Differences between the results from Tampen and the reference station on the Egersund Bank are also small. The report indicates that more attention should perhaps be paid to PAH discharges. A number of sources may contribute to PAH levels in the North Sea. This could be one of the topics addressed in the 2014 condition monitoring study.

5.2 Sediment monitoring Monitoring of the environmental condition of seabed sediments around Norwegian offshore installations has been under way since the late 1970s. Field-based surveys were conducted annually until 1996. Thereafter, monitoring around individual fields was incorporated in a regional programme which has been pursued until the present time.

Before any field is brought on stream, an investigation must be conducted to establish the base condition. Each region and field is investigated every third year to establish the physical, chemical and biological condition of the sediments. The monitoring is conducted by independent accredited consultants, and detailed guidelines ensure that results from different surveys are comparable across time and space.

These results are assessed by the government’s panel of experts, and made available in a common database operated by Norwegian Oil and Gas. Known as the MOD, this database is open to the general public and to researchers. The monitoring programme is among the most extensive conducted regularly on the North Atlantic seabed, and covers an estimated 1 000 stations on the NCS. Of these, about 700 are in the North Sea. Once the production phase has been completed, two further monitoring surveys are conducted at triennial intervals. The regional surveys in 2012 covered region II, Ormen Lange in region V and region VI. A limit of significant contamination (LSC) is established in the monitoring programme where the measured levels over various discharges exceed the background level

for the region. The LSC is not a fixed value, but varies from region to region and between different times.

The scientific findings

Region II – Sleipner ■ The THC level was by and large lower than or on a par with 2009.

■ The barium level had risen since 2009 on most fields in the region.

■ No fauna were found to have been disturbed on any of the fields as a result of petroleum operations.

■ The overall area with THCcontaminated sediments (>LSC) in the region was two-six square kilometres.

Region V – Ormen Lange ■ Generally speaking, the THC content was on a par with the two previous investigations. The level varied from about nine to 23 mg/kg. The estimated area with THC-contaminated sediments (LSC=20 mg/kg) in the region was 17 square kilometres.

■ Fauna on Ormen Lange were undisturbed by petroleum activities in the area.

Region VI – Halten Bank ■ Samples were acquired from 343 stations.

■ The estimated maximum area with THC-contaminated sediments (>LSC) had increased marginally, from 49 to 50 square kilometres.

■ The fauna surveys recorded a total of 1 160 065 individuals divided between 580 taxa (species or species groups).

■ The bristle worm Chaetozone sp, a known indicator for organic pollution, was among the 10 most dominant taxa.

The reason for this is unknown and cannot be related to petroleum activi- ties in the region, since the change was registered generally across the whole area.

■ Since the previous survey in 2009, the total area of fauna disturbance in region VI had declined from 3.29 to 0.73 square kilometres.

Environmental monitoring is an important tool for describing possible environmental impacts of discharges to the sea, both in the water column and on the seabed. The industry wants the impact of its discharges to be insignificant in the natural environment, and to cause no damage to the natural capacity for production or self-renewal.

25

6

Emissions to the air Power generation fuelled by natural gas or diesel oil is the main source of carbon and NOx emissions.

6.1 Emission sources Emissions to the air from the oil and gas industry consist of waste gases which contain CO2, NOx, SOx, CH4 and nmVOC from different types of combustion equipment. In most cases, emissions to the air are calculated from the amount of fuel gas and diesel oil used on the facility.

The emission factors build on measurements from suppliers, standard figures produced by Norwegian Oil and Gas on behalf of the industry, or field-specific measurements and calculations.

Emission sources

Other sources of hydrocarbon gas (CH4 and nmVOC) emissions are: ■ gas venting, minor individual leaks and other diffuse emissions from the installation ■ evaporation of hydrocarbon gases from storage and loading of crude oil offshore.

Power generation using natural gas and diesel as fuel is the main source of emissions of CO2 and NOx. The level of these emissions depends mainly on energy consumption by the facilities and the energy efficiency of power generation.

The second largest source of this emission type is gas flaring. This takes place to only a limited extent, pursuant to the provisions of the Petroleum Activities Act, but is permitted for safety reasons and in connection with certain operational problems.

The most important sources of CH4 and nmVOC emissions are offshore storage and loading of crude oil. During tank filling, volatile hydrocarbons vaporise into the tank atmosphere and mix with the inert gas added for safety reasons to eliminate the risk of explosion. Emissions occur as this mix is vented to the air when displaced by the entering crude oil.

Figure

The main sources of emissions to the air from oil and gas activities are: ■ fuel gas exhaust from gas turbines, engines and boilers ■ diesel exhaust from turbines, engines and boilers ■ gas flaring ■ combustion of oil and gas in connection with well testing and well maintenance.

SOx emissions primarily derive from the combustion of sulphur-containing hydrocarbons. Since Norwegian gas is generally low in sulphur, diesel oil is the principal source of such emissions on the NCS. Low-sulphur diesel oil is accordingly used.

Figure 15 presents emissions to the air

15

on the NCS compared with international averages. Norwegian production of oil and gas causes far lower emissions per unit of oe produced than in other countries, thanks to strict requirements and the industry’s strong focus on continuously reducing the amounts it releases.

Emissions to the air on the NCS compared with the international average

100 kg per scm oe produced

Source: OGP and Environment Web

Kg per scm oe produced

1.2

1.0

0.8

0.6

0.4

0.2

0.0 CO 2

NO x

CH 4

NCS 2011

International average for oil-producing countries 2011

nmVOC

SO 2

All figures are from 2011 because international figures for 2012 were not available in May 2013.

27

6.2 Emissions of greenhouse gases The UN has been the arena for international climate negotiations since the 1990s.

A climate convention adopted in Rio de Janeiro in 1992 defined the principal goals for international work in this area. Climate summits are held annually with all signatories to this convention. The 2013 meeting will take place in Bonn.

The first legally binding climate agreement was negotiated at Kyoto in Japan in 1997.

This protocol requires that the industrialised countries collectively cut their greenhouse gas emissions by at least five per cent in 2008-12 compared with the 1990 level.

A large number of developing countries are also signatories to the protocol, but do not have binding emission ceilings.

Figure

16

The 2011 climate summit at Durban in South Africa agreed in extra time on a road map towards a new global climate agreement embracing all countries. This is due to be negotiated by 2015 and to come into force in 2020. The Kyoto protocol has been extended with a second commitment period for the EU, Belarus, Iceland, Kazakhstan, Norway, Switzerland and Ukraine.

Emissions of carbon equivalent on the NCS million tonnes

14

13

12

11

10

0

28

2004

2005

2006

2007

2008

2009

2010

Oil and gas operations on the NCS release CO2, CH4 and an insignificant, unregistered quantity of N2O. Greenhouse gas emissions are registered in tonnes or converted to carbon equivalent in accordance with their global warming potential.

CH4 and nmVOC have a limited lifespan and are oxidised to CO2 in the atmosphere.

These short-lived climate forcers (SLCFs) accordingly have a double warming effect.

Indirect carbon emissions resulting from oxidation are therefore included in the greenhouse gas account. Total emissions of greenhouse gases from the NCS amounted to 13.1 million tonnes of carbon equivalent in 2012, on a par with the 2011 figure.

15

2003

The protocol covers emissions of CO2, CH4, nitrous oxide (N2O), perfluorocarbons (PFCs), hydrofluorocarbons (HFCs) and sulphur hexafluoride (SF6).

2011

2012

6.3 Short-lived climate forcers Short-lived climate forcers (SLCFs) are on the political agenda both in Norway and internationally.

Globally, work is being pursued in a number of initiatives through the Climate and Clean Air Act Coalition to Reduce SLCF, with the oil and gas directive having made the greatest progress. Ambitions are also enshrined in the Svalbard declaration of 2012 for the Nordic countries, the Arctic Council’s Tromsø declaration of 2009 involving eight Arctic nations, and the revised Gothenburg protocol of 2012.

On behalf of the Ministry of the Environment, Klif is working on a Norwegian action plan for reducing SLCFs which will include ozone, methane as a greenhouse gas and soot.

However, other SLCFs are also relevant.

cance of emissions from flaring as a contributor to climate change because of soot being deposited on snow and ice.

Growing attention is being paid to flaring emissions and impacts related to this type of substance. Establishing petroleum activities in Arctic regions increases the signifi-

■ current flaring systems/technology

SLCFs comprise particles and gases which are characterised by their big impact on climate and health, but short lifespan in the atmosphere. Reducing SLCF emissions would therefore have a swift effort on both climate and health. Where emissions occur is also very significant.

On that basis, Klif implemented a project on evaluating flaring strategy, techniques to reduce flaring and its emissions, emission factors and methods for determining emissions to the air from flaring. Running from the autumn of 2012 to the spring of 2013, this work has embraced flaring systems offshore and on land. The aim has been to learn about:

■ methods and techniques to reduce

flaring and emissions to the air, emission reductions achieved, and opportunities for and constraints on action.

Attention has also been given to company flaring strategies, and how these relate to company energy management and to emissions of greenhouse gases and other components. The companies have contributed to the project with extensive information from their own operations.

and criteria for selecting these

■ emission of NOx, CO2, SO2, methane,

nmVOCs and particles

29

6.4 Emissions of co2 Carbon emissions from operations on the NCS in 2012 totalled 12.4 million tonnes, a slight increase from 12.3 million in 2011. The petroleum industry has adopted measures which yielded documented emission reductions of more than 0.5 million tonnes in 2008-12.

Figure 17 shows carbon emissions from operations on the NCS and the distribution of emissions by source in 2012.

The biggest source of carbon emissions from oil and gas operations is turbines on offshore installations.

According to Statistics Norway, Norwegian emissions in carbon equivalent totalled 52.9 million tonnes in 2012, down by around 0.8 per cent from the year before.

The oil and gas industry accounted for about a quarter of this figure, roughly the same proportion as in 2011.

The breakdown by source changed little from 2011, and specific emissions from

Figure 18 presents the historical trend for flare gas consumption and associated carbon emissions, while figure 19 presents the historical development of direct and indirect carbon emissions per volume of hydrocarbons delivered in 2003-12.

Specific carbon emissions show a weakly rising trend, which reflects the rising water cut in wellstreams on aging fields as well as the growing proportion of gas requiring energy for compression before transport to Europe.

The industry is working continuously to reduce greenhouse gas emissions by enhancing energy efficiency and following up ambitions from the Konkraft reports (2007). An overall emission cut of one million tonnes per annum for the offshore oil and gas business in 2020 â&#x20AC;&#x201C; as also estimated by the Climate Cure (2010) â&#x20AC;&#x201C; is within reach. Heavy investment is also being made in technology development. Very interesting things are happening here in such areas as subsea solutions which substantially reduce energy consumption and thereby greenhouse gas emissions. Exports of such cleaner technology will help to reduce global greenhouse gas emissions, and recovery from the NCS will also be improved while maintaining low emissions per unit produced.

12.4

Direct carbon emissions (million tonnes) and by sourcE

14.0

Breakdown by source 2012 12.0

10.0

turbines 8.0

79.4 %

9.6 %

6.0

7.9 %

4.0

1.0 %

0.0 2003

30

engines

boilers

2.0

2004

2005

2006

2007

2008

2009

2010

2011

2012

well testing

flare

1.9 %

Mill tonnes

Figure

17

flaring were back at a stable level after the 2007-08 fluctuations caused by the start-up of the Hammerfest LNG plant and changes to conversion factors.

Platforms on Sleipner East.

Figure

Figure

18

Flare gas consumption and associated calculated carbon emissions

Flared gas (mill scm)

Specific carbon emissions (kg/scm oe)

Emissions (mill tonnes)

600

3.0

60

500

2.5

50

400

2.0

40

300

1.5

30

200

1.0

20

100

0.5

10

0

0

0 2003 2004 2005 2006 2007 2008 2009

19

2010

2011

2012

2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

31

6.5 Greenhouse gas emissions from Norwegian and international petroleum operations The oil and gas industry accounts for about a quarter of Norwayâ&#x20AC;&#x2122;s carbon emissions. Its share of national value creation measured by gross domestic product (GDP) is in the same order of size. That means the petroleum sector will be an important part of a climate solution.

A number of instruments are deployed by the Norwegian government to regulate emissions from the oil and gas business.

The most important of these are the carbon tax, Norwayâ&#x20AC;&#x2122;s participation in the EU emission trading market, flaring provisions in the Petroleum Activities Act, the requirement to assess power from shore when planning developments, emission permits and the BAT requirement. These instruments have prompted a number of measures by the petroleum sector. Broad-based studies conducted in recent years by both industry and government have documented that the Norwegian petroleum industry has acted to reduce its emissions.

The result is an offshore industry in the international premier division for energyefficient production and low carbon emisFigure

20

sions per unit produced. At the same time, certain other oil provinces are able to point to clear environmental improvements from instituting production patterns similar to those on the NCS, including reduced flaring.

The latter measure both cuts carbon emissions and boosts energy availability for more people, since the gas will then be consumed rather than flared.

All companies in Norway report all their emissions. This is a government requirement.

Certain other petroleum provinces make such reporting voluntary. In the Middle East, for example, emissions from only about a fifth of production were reported in 2011.

The Norwegian offshore sector is a world leader for its recovery factors. This means that a number of fields are mature, and recovering their remaining reserves is energy-

intensive. Norwayâ&#x20AC;&#x2122;s petroleum sector is nevertheless among the best in terms of low carbon emissions per unit produced.

The Norwegian petroleum industry is subject to double regulation in that it has paid carbon tax since 1991 and purchased emission allowances in the EU market since 2008.

Norwegian legislation on emission allowances will be harmonised with the EU regulations in 2013. That means the petroleum industry will receive free allowances for part of its emissions, on a par with similar activities in the EU. The Norwegian government presented a climate white paper in April 2012, which proposed an increase of NOK 200 per tonne in the carbon tax rate for the petroleum industry from 2013.

This has been implemented, and the tax is now NOK 410 per tonne of CO2.

Greenhouse gas emissions per unit produced in various petroleum provinces (kg of carbon equivalent per barrel of oe produced) Source: OGP and Environment Web

50

40

30

8 7 6

20 5 4

10

3 2 1

0 2003 1

32

Middle East

2004 2

Norway

2005 3

Europe

2006 4

Russia (FSU)

2007 5

South America

2008 6

2009 North America

2010 7

Asia/Australasia

2011 8

Africa

33

6.6 Power from shore The energy solution to be adopted when developing a new field must always be assessed by the licensees in their work on the plan for development and operation (PDO). Power from shore is implemented where the overall technical and financial conditions make this appropriate.

Ormen Lange, Troll A, Gjøa and Valhall are already supplied with electricity from land. Goliat will be partially powered from shore for reasons of safety, environmental protection and operations. It was decided in the spring of 2012 to develop the Martin Linge field in the northern North Sea with power from shore, while Statoil and the other licensees are assessing overall power from shore for new installations on the Utsira High (Johan Sverdrup, Edvard Grieg, Ivar Aasen and Dagny).

Hammerfest LNG, Melkøya.

34

Transmitting power from shore to NCS installations is much discussed as an emission-reduction measure. Since the main source of CO2 and NOx from the NCS is electricity generation from gas turbines, this approach would mean a considerable reduction in emissions from installations where an overall assessment found this be the best solution. Power from shore is relevant for new stand-alone developments and for major modification or conversion projects.

Sufficient generating and grid capacity must be available in the region, and such transmission must be cost-effective in relation to the resources to be recovered.

Large-scale transmission of power from shore to existing offshore installations is technically feasible, but studies show that it would be very expensive. On most existing installations, it would also replace only part of today’s energy production, making the abatement cost per tonne of greenhouse gas all the higher.

In its 2012 climate White Paper, the government stated that it aims to increase the use of power from shore. Decisions on electricity supply are conditional on sufficient additional power and grid capacity being available in the region, while abatement costs and natural diversity must be taken into account as well. The government has also announced that it intends to produce a major analysis of and strategy for power from shore as an energy solution for coordinated development of oil and gas fields close to each other. The NPD must be brought in before the choice of concept in development projects in order to ensure that the quality of the studies is satisfactory and that the alternatives have been given sufficient consideration.

Another stated government objective is that the southern part of the Utsira High should be supplied with power from shore.

Supplying electricity on an area basis poses significant challenges, including those related to decision-making across production licences and to projects in different phases. Commercial terms must be agreed between many parties – who will develop and operate, cost-sharing, uncertainties over producing lives and so forth. In addition comes the question of power availability on land and local challenges related to that.

6.7 Emissions of NOx NOx emissions from Norwegian petroleum operations totalled 50 704 tonnes in 2012. This was a small decline from 51 475 tonnes the year before.

Overall NOx emissions have changed relatively little in recent years.

Figure 21 presents NOx emissions from operations on the NCS and by source in 2011. According to Statistics Norway, Norwegian NOx emissions totalled 173 000 tonnes in 2012, a decline of

22

0.30 0.25 0.20

Figure 22 presents NOx emissions per volume of hydrocarbons delivered in 2003-12. Specific NOx emissions came to 0.22 kg/scm oe delivered in 2012, down from the year before.

0.15 0.10 0.05 0.0 03

Overall NOx emissions (tonnes) and by source

55 000

Breakdown by source 2012

50 000

39 %

40 000

1%

0 2003

2004

2005

2006

2007

2008

2009

2010

2011

04

05

06

07

08

09

10

11

12

50 439 59 %

Engines

45 000

NOx emissions per hydrocarbon delivered (kg/scm oe)

tonnes

Figure

21

roughly four per cent from the year before.

The oil and gas industry accounted for 29 per cent of this figure, a slight increase from 2011. The biggest source of NOx emissions from petroleum activities is turbines on offshore installations.

Figure

Their breakdown by source was influenced by a sharp reduction in the emission factor for calculating NOx emissions from flaring after 2007, while the volume of flaring at the Hammerfest LNG plant on Melkøya was unusually high in 2007. The breakdown by source is now stable.

turbines

flare

well testing

1%

2012

35

6.8 The NOx agreement and international obligations The environmental agreement on NOx regulates the commitments made to the government by Norwayâ&#x20AC;&#x2122;s industry associations on reducing their overall NOx emissions. Some 715 enterprises have signed up for the second agreement period in 2011-17, including all the operator companies on the NCS.

All the companies which have signed up to the agreement report their emissions to the business fund for NOx as the basis for invoicing their obligation to pay into the fund. Since its launch in 2008, the fund has considered more than 1 100 project applications. Of these, 470 have so far achieved verified reductions and thereby secured investment grants.

Although it is a substantial contributor to the fund, the oil industry has few implemented projects in receipt of grants because the cost of measures on the NCS is generally high. Big emission reductions have been achieved for each of the measures implemented.

The fund model in this environmental agreement ensures that emission reductions are implemented where they yield the biggest environmental return per krone spent.

Projects implemented had achieved verified NOx emission reductions by the deadlines specified which have so far met the

The fund has also made an important contribution to the development of new environmentally efficient solutions, and of new markets and market players. Examples include the further development of solutions for gas-fuelled ships, environment-friendly conversion of marine engines, use of catalytic converters to treat emissions with urea and the installation of fuel-efficient

Figure

The biggest reduction in NOx emissions during the first agreement period derived from service ships delivering to the oil and gas sector, followed by fishing vessels and then by merchant shipping in Norway and with services to Europe. The second period is witnessing a higher proportion of LNG projects for cargo carriers, tankers and ferries/passenger ships.

commitments in both first and second agreement periods. This scheme makes an important contribution to Norwayâ&#x20AC;&#x2122;s observance of the Gothenburg protocol.

23

One positive side effect is that emissions of carbon equivalent will also fall by 370 000 tonnes per annum from 2015 as a result of the projects implemented. This will represent a significant contribution to Norwegian emission reductions.

Breakdown of emission reductions by sector for measures supported by the NOx fund so far (2012) See: annual report of the NO x fund for 2012

rigs offshore

Cargo carriers tankers

Land-based industry

11%

3%

12%

12%

13%

Ferries/

passenger ships

36

solutions. Viewed overall, the market has both secured new development and expanded the use of established NOxreducing solutions. New suppliers have also secured help in a vulnerable phase in order to establish themselves in the market with support from the fund.

offshore service ships

35%

14 %

Fishing boats

6.9 Emissions of nmVOC Figure 24 presents nmVOC emissions from operations on the NCS and the breakdown of 2012 emissions by source. NmVOC emissions totalled 33 021 tonnes in 2012, a slight increase from the year before.

Overall nmVOC emissions have been cut by almost 88 per cent since 2001. These substantial reductions reflect investment in new facilities for removing and recovering oil vapour on storage ships and shuttle tankers.

Statistics Norway estimates total Norwegian nmVOC emissions in 2012 at 132 000 tonnes, with the oil and gas industry accounting for 25 per cent of this figure. Measures adopted offshore have made a significant contribution to Norwayâ&#x20AC;&#x2122;s opportunities for fulfilling its commitments under the Gothenburg protocol.

Total emissions of nmVOC (TONNes) and by source

200 000

Breakdown by source 2012

150 000

Diffuse emissions and cold venting

Loading

18 %

100 000

Storage 50 000

9%

33 021

tonnes

Figure

24

The largest source of nmVOC emissions from oil and gas operations remains storage and loading of oil, accounting for over 50 per cent of the total. This proportion has been steadily declining for a number of years because of the specific measures implemented on storage ships and shuttle tankers.

Cold venting and diffuse emissions account for the bulk of the remainder.

8%

53%

Other sources

0 2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

37

6.10 Emissions of CH4

The Oseberg C platform.

Figure 25 presents emissions of CH4 from operations on the NCS and the breakdown of these by source in 2012. Total CH4 emissions amounted to 25 658 tonnes in 2012, down from the year before.

According to Statistics Norway, Norwegian CH4 emissions totalled 207 477 tonnes in 2011. The petroleum sector accounted for 12.4 per cent of this figure.

Total emissions of CH4 (TONNes) and by source

40 000

Breakdown by source 2012 35 000

30 000

71%

25 000

16 %

20 000

25Â 658 Diffuse emissions and cold venting

Other sources

15 000

10 000

11%

Loading 5 000

0 2003

38

2004

2005

2006

2007

2008

2009

2010

2011

2012

Storage

1%

tonnes

Figure

25

The share of emissions from offshore loading has declined drastically over the years and now accounts for about 11 per cent of the total. Cold venting and diffuse emissions from flanges, valves and various types of process equipment represent the biggest sources of CH4 emissions from the oil and gas industry.

6.11 Emissions of SOx

The Aker Barents drilling rig.

Figure 26 shows SOx emissions from operations on the NCS and by source in 2012.

Total emissions in that year came to 822 tonnes, down from 2011.

According to Statistics Norway, Norwegian SOx emissions totalled 18 000 tonnes in 2011.

The petroleum sector accounted for 4.5 per cent of this figure.

822

Overall emissions of SOx (TONNes) and by source

1 000

Breakdown by source 2012

Turbines

800

19.0%

600

Flare

26.1%

400

tonnes

Figure

26

The largest source in the oil and gas industry is burning diesel oil in engines, while flaring accounted for most of the increase in overall emissions since 2010.

Engines

50.1%

200

3.2% 0 2003

2004

2005

2006

2007

2008

2009

2010

2011

Boilers

Well testing

1.5 %

2012

39

7

Waste Norwegian Oil and Gas has developed its own guidelines for waste management in the offshore sector.

Waste from the oil and gas industry is divided into hazardous and non-hazardous categories, and must be declared pursuant to national regulations and international guidelines. The principal goals of the operators, defined in common guidelines for waste management in offshore oil operations, is to generate a minimum of waste and to establish systems for recycling as much of it as possible.

Norwegian Oil and Gas has developed its own guidelines for waste management in the offshore sector.

These are used in declaring and further treatment of the waste.

Non-hazardous waste totalled 29 692 tonnes in 2012. This figure has varied between 20 000 and 30 000 tonnes since 2006.

Figure

27

Breakdown of non-hazardous waste from the offshore industry (2012)

Wet organic waste

0.4%

Wood

Residual waste

Plastic Brown paper Paper

2.3 %

1.5 %

3.7%

8.7%

7.9 %

Other

23.7%

Abrasive sand Electrical and electronic waste Glass

11.4%

0.4 %

0.0%

2.3%

Food-contaminated waste

Metals

37.7%

41

Hazardous waste totalled about 314 000 tonnes in 2012, down slightly from the year before. The largest proportion, almost 300 000 tonnes, is oily water (oil emulsion and slops) and drilling waste (drilling fluids based on mineral oil and drill cuttings).

A substantial growth in drilling waste has occurred over the past two years (see figure 28). This primarily reflects problems with leaks from injection wells on several fields, which prompted a halt to further injection.

That in turn meant that large volumes of oily waste which was previously injected had to be sent ashore for treatment.

Figure

28

Handling of drill cuttings on this type of field is organised for slurrying to simplify injection. The cuttings are crushed and mixed with water, which substantially expands their volume. This practice continued, and cuttings were sent ashore as slurry â&#x20AC;&#x201C; which contributed to a big increase in the volume of drilling waste.

Injection provides substantial environmental benefits and can be cost-efficient compared with final treatment on land.

The operators have initiated a number of measures to prevent future leaks from injection wells. With better preliminary

Oil-contaminated waste sent ashore, volume developments (tonnes)

300 000

Low-level radioactive waste

The rocks from which oil and gas are produced contain a number of minerals and metals, some of which are weakly radioactive. Such substances accompany both oil and gas during production, but are contained mostly in the produced water separated from the oil on the platform.

Before discharge, this water is treated to remove oil residues and particles. The oil waste separated from produced water on some fields will be categorised as radioactive.

Low-level radioactive waste from the oil and gas industry is included in the oily waste category, and treated in accordance with the requirements and guidance specified in the radiation protection regulations and associated guidelines issued by the Norwegian Radiation Protection Authority.

New regulations for low-level radioactive waste came into force in 2011. This waste is divided into two categories: one for activity above 10 Bq/g (3022-1) and the other for activity between 1-10 Bq/g (3022-2). While both categories are treated in the same way as before, the new regulations provide a better overview of the total quantities. Categories 3022-1 and 3022-2 totalled 33.3 and 57.8 tonnes respectively in 2012.

250 000

200 000

150 000

100 000

50 000

0 2003

2004

2005

Drilling mud and cuttings

42

surveys and the other action taken, injection is likely to increase in coming years. New injection wells have now been drilled on several fields, which are either operational or will become so during 2013. This explains the reduction of about 45 000 tonnes in drilling mud and drill cuttings from 2011 to 2012. Slurrying of cuttings is likely to cease on platforms where injection has not been resumed. That will contribute to a further reduction in the volumes being sent ashore.

2006

2007

Oil emulsions

2008

2009

2010

2011

2012

43

8

TABLES

TABLE

01

HISTORICAL PRODUCTION DATA FOR OIL, CONDENSATE, GAS AND WATer (mill scm, GAS bn scm)

Gross oil

Net gas

Gross gas

Net condensate

Gross condensate

Net NGL

2000

181 181

182 126

49 748

90 385

6 277

8 847

7 225

2001

180 884

182 071

53 895

95 041

6 561

9 310

10 924

2002

173 649

173 391

65 501

107 521

8 020

11 895

11 798

2003

165 475

164 295

73 124

118 265

11 060

15 585

12 878

2004

162 777

161 064

78 465

127 753

9 142

15 130

13 621

2005

148 137

144 776

84 963

130 807

8 422

16 395

15 735

2006

136 577

131 396

87 613

129 533

7 989

17 614

16 672

2007

128 277

119 538

89 662

136 697

3 474

16 544

16 577

2008

99 231

141 269

4 180

17 276

16 022

122 668

113 335

2009

115 443

106 116

103 464

144 526

4 421

17 364

16 048

2010

104 333

96 293

106 421

145 017

4 121

15 305

15 457

2011

97 480

89 683

103 353

141 538

4 551

15 152

16 294

2012

89 230

81 916

114 918

152 661

4 548

15 022

17 713

TABLE

02

Tables

Net oil

Reporting year

INJECTION DATA (scm)

Reporting year

Injected seawater

Injected gas

Gross fuel gas

Gross flared gas

2000

225 122 366

35 263 257 573

3 135 476 082

704 977 418

2001

236 185 208

28 735 573 767

3 183 903 441

552 518 130

2002

239 216 244

33 249 106 525

3 633 399 130

425 750 692

2003

276 860 649

37 831 830 628

3 787 566 522

437 108 442

2004

277 454 051

42 080 845 665

3 944 034 988

426 283 524

2005

256 584 671

38 673 146 648

3 911 535 767

436 855 779

2006

229 580 409

35 888 052 471

3 804 416 091

396 828 489

2007

217 684 641

39 803 151 739

3 759 923 126

367 856 958

2008

201 787 094

33 841 511 529

3 732 706 712

447 344 171

2009

171 931 383

33 524 109 000

3 665 580 404

358 746 213

2010

157 806 890

31 234 573 000

3 612 680 129

352 504 024

2011

144 361 059

30 387 968 000

3 515 184 381

352 747 688

2012

141 172 398

29 331 500 000

3 579 740 030

325 791 139

45

TABLE

03

DRILLING WITH OIL-BASED DRILLING FLUIDS (TONNES)

Reporting year

Drilling fluids Discharged (volume)

Drilling fluids Injected

Drilling fluids Transported to land

Base fluids Left in hole or lost to formation

2004

132 062

0

60 087

23 422

48 414

2005

217 852

0

64 486

44 699

52 020

TABLES

2006

183 702

0

58 205

38 989

48 343

2007

182 364

0

53 301

42 660

50 837

2008

183 225

0

51 819

50 051

50 356

2009

220 394

0

45 728

71 567

54 270

2010

105 151

0

27 438

55 220

64 789

2011

112 863

0

14 954

55 895

47 456

2012

113 162

0

18 356

56 238

42 713

TABLE

04

DRILLING WITH SYNTHETIC DRILLING FLUIDS (TONNES)

Reporting year

Drilling fluids Consumption

Drilling fluids Discharged (volume)

Drilling fluids Injected

Drilling fluids Transported to land

Base fluids Left in hole or lost to formation

826

0

439

1 030

2004

2 298

2005

5 303

0

0

4 039

1 263

2006

0

0

0

0

0

2007

0

0

0

0

0

2008

968

0

0

630

338

2009

0

0

0

0

0

2010

0

0

0

0

0

2011

2 888

0

0

1 126

1 762

2012

0

0

0

0

0

TABLE

05

DRILLING WITH water-BASED DRILLING FLUIDS (TONNES)

Reporting year

2004

46

Drilling fluids Consumption

Drilling fluids Consumption

Drilling fluids Discharged (volume)

Drilling fluids Injected

Drilling fluids Transported to land

Base fluids Left in hole or lost to formation

239 889

199 429

15 684

2 940

20 329

2005

219 126

153 352

21 879

17 082

20 804

2006

267 310

196 680

22 139

9 956

23 634

2007

265 754

199 281

27 243

9 439

16 982

2008

265 668

169 442

33 151

20 590

25 516

2009

419 440

285 662

20 320

24 717

31 417

2010

166 513

231 378

12 162

15 341

31 802

2011

288 293

228 222

30 302

21 888

35 967

2012

326 822

238 652

25 371

26 272

41 525

TABLE

06

DISPOSAL OF CUTTINGS FROM DRILLING WITH OIL-BASED DRILLING FLUIDS (TONNES)

Reporting year

2003

Cuttings Exported to other fields

Cuttings Discharged to sea

Cuttings Volume injected

Cuttings Transported to land

Total amount generated cuttings/mud

5 612

0

110 231

49 676

176 598

2004

0

0

51 691

20 329

148 071

2005

0

0

60 242

20 287

246 018 211 942

0

0

54 433

22 679

467

0

50 321

28 875

191 191

2008

0

0

49 108

24 275

228 743

2009

424

0

47 640

39 072

252 562

2010

0

0

26 938

81 188

125 123

TABLE

2011

0

0

19 699

68 190

64 614

2012

0

0

23 409

65 689

93 141

Cuttings Discharged to sea

Cuttings Volume injected

Cuttings Transported to land

86 061

1 726

58

07

DISPOSAL OF CUTTINGS FROM DRILLING WITH WATER-BASED FLUIDS (TONNes)

Reporting year

Cuttings Exported to other fields

2004 2005

72 684

895

893

325

80 757

1 423

2 226

2007

0

86 405

1 191

722

2008

651

70 199

2 717

2 501

2006

2009

0

132 003

1 624

251

2010

0

207 655

664

9 896

2011

0

195 062

5 741

10 885

2012

0

171 841

1 169

3 774

TABLE

08

Tables

2006 2007

TOTAL AMOUNT OF CUTTINGS/MUD IMPORTED TO FIELDS (TONNes)

Reporting year

Oil-based

Reporting year

Oil-based

1997

766

2005

3 268

1998

1 926

2006

2 383

1999

0

2007

1 668

2000

852

2008

3 692

2001

5 926

2009

7 579

2002

0

2010

14 994

2003

5 600

2011

91

2004

0

2012

0

47

TABLE

09

SELECTED GROUPS OF ORGANIC COMPOUNDS DISCHARGE IN PRODUCED WATER (KG)

Substance

2003

Others

2005

2006

2007

2008

2009

2010

2011

2012

TABLES

2 743 449

8 025 465

8 131 449

7 519 086

7 959 150

8 838 787

7 814 585

7 905 978

8 611 126

8 424 293

BTEX

861 160

1 485 212

1 479 637

1 644 661

1 826 674

1 803 998

1 902 925

1 818 173

1 675 059

1 855 037

Alkylphenols C1-C3

281 116

278 173

257 668

335 937

341 254

324 626

310 191

310 217

298 324

300 662

Alkylphenols C4-C5

10 104

12 809

13 273

15 571

12 513

12 473

12 949

10 258

14 360

15 892

Alkylphenols C6-C9

401

225

302

132

173

198

184

294

219

124

184 168

206 962

170 118

179 405

212 822

207 560

185 041

166 660

179 546

206 564

Phenols Oil in water

1 698 382

2 075 894

2 097 498

1 057 837

1 178 851

947 549

1 156 501

1 200 078

1 235 608

1 325 326

33 576 880

32 754 134

34 711 299

34 838 267

35 818 064

31 263 700

27 204 909

24 752 275

22 251 835

22 144 558

Total EPA-PAH

45 176

61 860

44 392

66 968

52 567

48 312

51 512

1 541

1 863

1 794

PAH

99 465

110 511

121 454

89 899

73 776

81 157

101 664

140 867

155 915

166 366

Organic acids

TABLE

10

BTX COMPOUNDS DISCHARGE IN PRODUCED WATER (KG)

Substance

Benzene Ethylbenzene

2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

446 233

682 490

683 080

771 347

871 200

862 411

868 175

832 031

771 333

848 713

19 074

35 533

32 648

34 271

34 565

34 675

46 135

41 758

37 913

43 761

Toluene

272 080

554 030

571 545

628 213

674 719

672 398

722 851

700 550

655 169

710 617

Xylene

123 772

213 160

192 364

210 830

246 189

234 513

265 764

243 835

210 644

251 946

TABLE

11

Substance

HEAVY METALS DISCHARGE IN PRODUCED WATER (KG)

2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

Arsenic

471

360

267

380

660

614

483

895

656

604

Barium

1 925 471

7 124 440

7 015 319

6 137 119

6 939 336

7 762 350

7 008 907

7 071 530

7 639 584

7 554 262

527

273

173

348

255

386

290

239

428

309

714 214

888 912

1 108 015

1 370 415

1 008 440

1 058 121

797 369

825 822

959 698

863 198

32

20

11

30

28

41

28

22

32

18

3 991

3 639

312

730

103

102

102

89

162

143

Chrome

117

231

4 018

192

175

213

154

225

221

131

Mercury

7

9

8

7

6

11

9

9

15

13

407

452

1 073

735

299

299

142

200

223

198

11 211

7 130

2 253

9 129

9 847

16 651

7 100

6 948

10 108

5 418

Lead Iron Cadmium Copper

Nickel Zinc

48

2004

TABLE

12

PHENOLS DISCHARGE IN PRODUCED WATER (KG)

Substance

2004

2005

2006

2007

2008

2009

2010

2011

2012

C1-Alkylphenols

182 012

167 582

161 542

214 511

226 609

207 855

203 376

199 007

186 923

190 276

C2-Alkylphenols

76 922

79 333

70 094

92 631

82 571

87 634

80 707

83 860

82 207

70 392

C3-Alkylphenols

22 181

31 258

26 032

28 794

32 074

29 137

26 108

27 350

29 194

39 995

C4-Alkylphenols

7 827

11 013

11 115

12 524

10 438

10 451

11 624

8 707

11 195

11 315

C5-Alkylphenols

2 277

1 796

2 157

3 047

2 076

2 022

1 325

1 551

3 165

4 577

C6-Alkylphenols

125

95

66

51

86

84

78

125

81

52

C7-Alkylphenols

77

51

62

20

26

61

22

55

61

53

C8-Alkylphenols

123

50

81

37

33

39

20

71

45

11

C9-Alkylphenols

76

28

92

23

28

13

64

44

31

8

184 168

206 962

170 118

179 405

212 822

207 560

185 041

166 660

179 546

206 564

Phenols

TABLE

13

Tables

2003

ORGANIC ACIDS DISCHARGE IN PRODUCED WATER (KG)

Substance

Butyric acid Acetic acid Formic acid

2002

2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

644 737

755 601

709 758

752 861

671 281

777 200

714 602

627 237

519 296

453 964

456 609

24 589 094

28 685 218

28 272 473

29 820 022

29 837 132

30 327 152

26 381 307

22 509 255

20 693 558

19 028 018

19 045 328

65 731

152 368

209 953

159 966

501 911

449 707

314 221

563 669

493 913

450 016

341 274

259 322

262 712

283 637

250 405

264 051

179 185

99 691

96 547

Naphthenic acid Valeric acid Propionic acid

256 215

298 361

312 267

336 195

344 439

374 276

341 590

338 214

241 354

159 998

165 674

3 499 928

3 685 331

3 249 683

3 382 933

3 220 793

3 606 091

3 261 575

2 902 484

2 624 969

2 060 148

2 039 125

49

TABLE

14

PAH COMPOUNDS DISCHARGE IN PRODUCED WATER (KG)

2002

2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

Acenaphthene**

226

252

264

276

238

200

164

198

196

225

217

Acenaphthylene*

32

36

38

155

185

45

174

93

83

94

93

Anthracene*

41

113

94

118

36

36

60

10

7

9

8

Benzo(a)anthracene*

30

42

26

32

29

13

18

9

8

8

9

Benzo(a)pyrene*

10

12

10

11

14

6

5

4

3

3

3

Benzo(b)fluorantene*

16

24

16

25

132

13

16

9

9

10

10

Benzo(g,h,i)perylene*

12

17

9

21

17

5

7

6

6

6

6

Benzo(k)fluorantene*

15

4

4

5

13

2

4

2

1

1

1

C1-dibenzothiophene

1 230

1 106

1 576

1 953

1 521

690

761

667

601

716

808

C1-Phenanthrene

1 980

3 483

2 935

3 238

1 345

1 886

1 589

2 438

2 222

2 873

2 957

51 647

44 188

57 796

59 929

50 250

43 939

44 155

47 410

45 000

49 202

54 446

C2-dibenzothiophene

1 282

1 404

1 476

2 096

1 453

663

634

939

878

1 160

1 217

C2-Phenanthrene

2 177

3 785

2 603

3 344

1 982

1 823

1 976

2 706

2 598

3 747

3 748

20 667

26 021

25 248

27 251

21 143

16 086

19 636

24 669

21 880

26 936

27 707

9 191

119

263

474

342

71

92

20

22

27

26

737

517

635

466

187

375

306

662

694

1 157

1 111

11 453

18 227

17 359

21 957

11 226

7 813

11 614

21 719

17 219

22 363

23 230

8

10

7

9

12

3

4

3

2

3

2

482

615

619

748

449

429

394

435

407

465

518

Phenanthrene

1 821

2 217

2 332

2 553

1 723

1 518

1 565

1 712

1 576

1 775

1 781

Fluoranthene*

47

56

39

88

53

38

28

25

27

45

37

1 200

1 683

1 620

1 769

1 308

1 132

1 166

1 175

1 126

1 384

1 327

6

6

4

5

12

2

3

2

1

1

2

68

43

57

74

61

40

61

42

30

41

38

43 622

40 545

57 243

39 133

63 073

49 450

44 963

48 175

47 770

45 492

48 816

52

116

97

117

64

64

74

49

43

34

42

Substance

TABLES

C1-naphthalene

C2-naphthalen C3-dibenzothiophene C3-Phenanthrene C3-naphthalene Dibenz(a,h)anthracene* Dibenzothiophen

Fluorene* Indeno(1,2,3-c,d)pyrene*

Chrysene* Naphthalene Pyrene* * Included in the EPA-16 total

50

TABLE

15

Klif colour category

Green

Red

Black

Reporting year

2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

Discharge

118 388

91 044

80 105

93 141

113 159

114 403

159 569

127 249

138 019

146 620

Consumption

320 685

296 941

296 091

303 976

338 485

344 559

385 425

374 541

351 387

368 199

Discharge

10 977

10 599

10 240

11 078

12 005

12 819

14 701

11 727

12 305

13 532

Consumption

79 178

83 915

85 297

90 592

94 905

94 500

92 410

103 061

80 141

82 714

626

299

93

39

23

15

32

16

8

8

7 661

7 852

6 375

5 659

5 376

4 261

3 206

2 894

1 842

2 088

5

2

3

3

1

2

1

1

1

2**

218

211

121

40

50

60

16

1 259*

1 140*

746**

Discharge Consumption

Discharge Consumption

Tables

Yellow

DISCHARGE AND CONSUMPTION OF CHEMICALS

BY KLIF COLOUR CATEGORy (TONNes)

* From 2010, includes consumption of hydraulic oil in closed systems. ** From 2012, includes discharge of fire-extinguishing foam.

TABLE

16

DISCHARGE OF CHEMICALS

BY KLIF COLOUR CATEGORy (TONNes)

Klif colour category

Green

Yellow

Red

Black

1997

114 778

39 684

3 933

228

1998

142 646

10 971

2 441

34

1999

162 603

9 495

1 839

21

2000

187 323

14 184

1 337

18

2001

167 365

11 834

1 117

45

2002

164 450

10 898

1 022

35

2003

118 388

10 977

626

5.2

2004

91 044

10 599

299

2.1

2005

80 105

10 240

93

3.2

2005

93 141

11 078

39

3.2

2007

109 778

11 796

23

1.1

2008

114 403

12 819

15

2.5

2009

159 569

14 701

32

1.1

2010

127 249

11 727

16

1.4

2011

138 019

12 305

8

0.6

2012

146 620

13 532

8

2.4*

* From 2012, includes discharge of fire-extinguishing foam.

51

TABLE

17

discharge of OIL-CONTAMINATED WATER

Water type

2002

2003

2004

2005

9

7

16

21

13

11

32

Water volume to sea (cu.m)

1 390 614

711 201

663 964

1 148 995

Total water volume (cu.m)

1 437 979

818 045

722 460

1 200 245

47 296

106 817

57 186

51 515

73

113

76

255

146

158

119

Water volume to sea (cu.m)

60 218 998

56 862 577

53 326 642

47 403 128

Total water volume (cu.m)

60 218 998

56 850 991

53 326 642

47 403 128

32

42

67

61

3

31

1 474

1 511

1 510

2 572

2 276

2 293

2 871

Water volume to sea (cu.m)

118 932 533

134 729 541

142 803 237

147 269 373

Total water volume (cu.m)

136 323 268

156 391 243

173 892 780

177 388 172

16 636 832

21 286 897

29 794 046

32 569 423

Drainage

TABLES

Oil index volume to sea (tonnes) Dispersed oil volume to sea (tonnes)

Injected water volume (cu.m)

Displacement Oil index volume to sea (tonnes) Dispersed oil volume to sea (tonnes)

Injected water volume (cu.m)

Jetting Oil index volume to sea (tonnes) Dispersed oil volume to sea (tonnes)

8

Water volume to sea (cu.m) Total water volume (cu.m) Injected water volume (cu.m)

Produced Oil index volume to sea (tonnes) Dispersed oil volume to sea (tonnes)

Injected water volume (cu.m)

52

2007

2008

2009

2010

2011

2012

9

8

10

6

8

7.85

8

13

2

0

0

0

0

902 487

905 396

953 964

917 986

727 811

867 531

953 596

979 867

962 543

993 156

1 099 819

763 736

891 951

979 802

77 086

53 328

36 298

184 247

19 875

16 740

18 831

78

94

58

55

47

50.5

58

0

0

0

0

133 41 633 651

42 080 398

35 781 227

31 567 044

31 953 823

27 025 783

31 491 555

41 633 651

42 080 398

35 781 227

31 567 050

31 953 823

27 025 783

31 491 555

0

0

0

0

0

26

13

24

65

53.1

43

1 532

1 569

1 487

1 443

1 478

1 535

144 741 847

161 825 645

149 241 700

134 770 215

130 842 793

128 550 571

130 909 973

173 349 396

182 807 754

173 375 110

158 559 726

157 890 256

160 758 982

162 958 696

31 693 056

26 665 258

30 379 135

29 547 450

33 217 136

31 095 328

32 756 572

15

Tables

2006

25

1 308 2 441

53

TABLE

18

TOTAL CONSUMPTION, DISCHARGE AND INJECTION OF CHEMICALS

BY APPLICATION (TONNes)

2002

2003

2004

2005

143 237

103 226

74 379

63 116

89 406

80 993

82 800

80 640

Consumed

533 410

335 015

321 131

320 491

Discharged

10 646

9 733

10 481

10 555

Application

Discharged Drilling and well chemicals

TABLES Gas processing chemicals

Auxiliary chemicals

Injected

Injected

411

455

3 141

412

Consumed

14 796

13 466

16 789

14 540

Discharged

2 566

2 293

2 391

1 919

Injected Consumed

Discharged Injection chemicals

Chemicals from other production locations

Chemicals added to the export flow

Production chemicals

Reservoir management

Pipeline chemicals

344

403

3 525

2 962

185

283

1 049

1 335

501

215

687

Consumed

13 441

14 095

14 666

15 115

Discharged

9 913

1 259

1 533

1 140

153

228

338

419

Injected Consumed

64

Discharged

9

113

Consumed

14 616

7 032

4 941

7 805

Discharged

8 582

11 343

11 722

11 131

282

Injected

Injected

1 579

4 051

3 706

2 995

Consumed

22 013

32 206

26 865

24 405

Discharged

1

3

Consumed

1

3

1

1

Discharged

1 259

1 746

389

962

1

Injected

Injected

Total discharged Total injected Total consumed 54

300 3 929

3 332

Injected

Consumed

total

162 4 161

17

20

1 265

1 898

663

2 159

176 398

129 996

101 944

90 441

94 890

86 318

90 360

85 385

603 767

407 643

388 919

387 897

2007

2008

2009

2010

2011

2012

72 641

87 682

90 841

137 008

104 966

111 839

112 391

79 872

78 166

88 506

65 682

44 204

37 685

36 627

323 238

352 533

357 736

402 110

409 337

357 665

373 038

13 062

11 619

13 124

11 849

9 698

11 097

16 079

1 241

757

1 502

1 634

1 406

1 628

4 133

17 760

18 804

22 257

21 381

17 905

21 061

22 563

2 223

3 622

4 031

4 795

4 244

4 489

4 903

369

250

810

501

420

377

190

3 279

6 269

7 135

7 886

8 091

8 073

7 671

132

332

235

200

188

212

176

1 742

1 464

1 486

1 485

1 367

1 492

2 945

14 730

15 361

15 517

12 997

11 487

9 830

9 155

917

697

847

753

753

692

952

59

41

210

24

117

114

150

438

434

614

475

536

0

0

188

311

439

1 664

1 847

1 483

1 951

0

0

0

0

0

5 866

5 180

5 443

5 085

5 094

4 665

5 269

14 049

15 317

17 208

17 033

16 001

17 272

19 577

5 881

3 323

4 046

4 500

4 403

4 598

4 082

30 069

29 131

31 278

27 720

26 816

28 564

29 018

1

2

0

9

5

2

3

0

0

0

0

0

0

1

2

14

12

14

6

4

1 049

2 015

516

917

1 308

3 245

4 130

0

146

599

936

494

4 886

5 189

3 385

2 973

2 477

4 609

7 029

104 260

121 597

127 240

174 228

139 009

150 332

160 162

89 165

84 000

96 560

73 973

52 515

46 829

48 621

400 267

432 904

443 381

480 640

481 756

434 472

453 747

Tables

2006

55

TABLE

TABLES 56

19

CONSUMPTION AND DISCHARGE OF CHEMICALS

BY ENVIRONMENTAL PROPERTIES (KG)

Klif category description

Klif colour category

Other chemicals

Yellow

Biodegrability < 20%

Red

Biodegrability < 20% and toxicity EC50 or LC50 ≤ 10 mg/l

Black

Biodegrability < 20% and log Pow ≥ 5

Black

Hormone-disrupting substances

Black

Chemicals on Plonor list

Green

List of priority chemicals included in result target 1 (Priority List) White Paper no 25 (2002-2003)

Black

Two out of three categories: biodegradability < 60%, log Pow ≥, EC50 or LC50 ≤ 10 mg/l

Red

Water

Green

Yellow in sub-category 1. Expected to biodegrade completely.

Yellow

Yellow in sub-category 1. Expected to biodegrade into substances which are not environmentally hazardous.

Yellow

2003

2004

2005

Consumption

79 178 438

83 914 962

85 297 097

Discharge

10 976 671

10 599 282

10 240 472

3 450 264

3 674 490

2 997 005

331 007

210 125

59 872

35 837

115 260

50 683

2 257

403

685

180 826

95 102

69 251

2 653

1 486

2 365

199

175

150

237 163 198

226 931 564

228 475 800

78 976 339

63 581 604

56 369 558

Consumption

843

812

1 032

Discharge

41.3

20.3

3.3

4 022 934

3 953 650

3 378 432

292 911

81 489

33 273

Consumption

83 521 489

70 009 327

67 614 818

Discharge

39 411 378

27 462 007

23 735 816

Consumption Discharge

Consumption Discharge

Consumption Discharge

Consumption Discharge

Consumption Discharge

Consumption Discharge

Consumption Discharge

Consumption Discharge

1

2007

2008

2009

2010

2011

2012

90 591 982

94 904 859

94 500 238

92 409 851

103 061 375

80 140 772

68 288 728

11 077 604

12 004 946

12 818 860

14 701 037

11 727 338

12 304 885

7 574 427

2 928 386

3 016 508

3 079 264.00

2 144 671

2 386 670

1 493 063

1 287 072

17 794

13 236

10 515

16 318

14 455

6 403

3 600

31 908

4 141

1 405

1 233

20 616

11 994

10 853

2 147

398

459

66

80

108

1 050

7 464

990

908

1 173

1 238 234

1 128 385

694 302

861

569

824

1 010

1 275

405

64

19 800

13 758

0

28

4

494 206

100

1 027

61

91

54

10

227 535 746

251 002 945

252 779 521

289 681 616

286 277 021

273 273 649

282 200 932

63 423 630

72 584 564

74 569 494

111 268 937

90 611 749

99 503 072

103 431 611

594

497

146

58

6

3

6.6

0.6

140

19.6

0

3

2 730 168

2 359 348

1 181 523

1 061 115

506 942

348 519

801 011

21 317

9 500

4 579

15 830

1 584

1 710

3 904

76 440 340

87 481 939

91 779 833

95 743 461

88 264 187

78 113 608

85 997 959

29 716 997

40 574 911

39 833 569

48 300 298

36 637 585

38 515 435

43 188 663

Tables

2006

7 335 852 3 708 051

4 988 993 1 767 544

57

TABLE

20

DISCHARGE OF CONTAMINANTS IN CHEMICALS (TONNes)

2002

2003

2004

3.24

0.139

0.104

0.013

0.144

0.057

0.073

0.067

0.178

0.200

4.18

1.94

1.1

1.63

2.29

2.35

1.39

0.056

0.012

0.011

0.006

0.010

0.009

Copper

3.23

3.09

1.76

1.08

1.78

Chrome

0.694

0.809

0.58

0.458

Mercury

0.021

0.008

0.006

0.004

Substance

Other Arsenic Lead

TABLES

Cadmium

2007

2008

2009

2011

2012

0.149

0.176

0.512

2.56

1.47

1.48

3.51

0.011

0.020

0.012

0.014

0.063

2.02

2.1

3.94

3.13

1.67

0.482

0.565

0.512

0.821

0.728

0.775

0.88

0.005

0.004

0.003

0.008

0.004

0.008

0.011

0.228

DISCHARGE OF CONTAMINANTS IN CHEMICALS TOTAL VOLUME (TONNes)

Reporting year

58

2006

Discharge

2010 0.14

TABLE

TABLE

21

2005

22

DISCHARGE OF CHEMICAL ADDITIVES TOTAL VOLUME (TONNes)

Reporting year

Discharge

1997

21.7

1997

20.4

1998

46.4

1998

13.2

1999

18.5

1999

10.5

2000

33.9

2000

11.3

2001

9.9

2001

3.29

2002

13.1

2002

1.01

2003

9.1

2003

0.36

2004

3.7

2004

0.16

2005

3.2

2005

0.09

2006

4.9

2006

0.01

2007

5.0

2007

1.58

2008

4.2

2008

0.01

2009

7.5

2009

1.53

2010

5.6

2010

0.06

2011

4.1

2011

0.07

2012

5.0

2012

1.03

TABLE

23

ACUTE DISCHARGES TO THE SEA

Type of discharge

2002

2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

Number > 1 cu.m

40

60

31

37

27

40

30

42

32

28

38

Total number > 0.05 cu.m

19

25

30

44

35

22

36

59

64

58

58

Total number 0.05-1 cu.m

42

49

48

49

40

47

66

61

62

65

52

Volume > 1 cu.m

331

915

679

402

429

5 403

347

13 029

6 245

176

350

Total volume < 0.05 cu.m

0.3

28.8

0.5

0.6

0.4

0.3

0.4

0.6

0.6

0.6

0.6

Total volume 0.05-1 cu.m

12.4

17.2

18.8

14.8

13.5

11.7

18.8

22.9

20.0

24.5

14.8

Total number

101

134

109

130

102

109

132

162

158

151

148

Total volume (cu.m)

344

961

696

418

443

5 415

366

13 052

6 265

201

365

9

11

10

6

7

12

9

4

7

1

4

Total number > 0.05 cu.m

173

75

71

85

78

112

130

106

109

101

96

Total number 0.05-1 cu.m

65

46

37

56

37

42

34

37

24

28

22

89.8

821

68.7

361

113

4 476

186

104

105

10

9

Total volume < 0.05 cu.m

2

43.1

0.9

0.9

0.9

1.0

1.0

0.6

0.6

0.6

0.6

Total volume 0.05-1 cu.m

17.1

13.1

7.1

15

7.9

11.2

7.9

9.3

4.9

8.1

6.4

Total number

247

132

118

147

122

166

173

147

140

130

122

Total volume (cu.m)

109

877

76.7

377

122

4 488

195

114

111

19

16.3

Chemicals

Tables

oil Number > 1 cu.m

Volume > 1 cu.m

59

TABLE

24

Emissions CO2 (tonnes) direct

Emissions PAH (tonnes)

Emissions NOx (tonnes)

Emissions SOx (tonnes)

Emissions PCB (tonnes)

Emissions dioxin (tonnes)

Volume fuel gas (cu.m)

Volume liquid fuel (tonnes)

Discharge to the sea from well tests (tonnes)

1997

8 697 352

0.406

43 414

565

0.00065

3.00E-08

3 410 664 587

232 360

29.5

1998

9 388 957

0.274

45 733

779

0.0005

0.000000023

3 651 323 015

258 447

22.5

1999

9 538 416

0.214

45 461

815

0.00039

0.000000018

3 479 407 122

268 719

8.2

2000

10 786 850

0.563

52 314

1109

0.00103

0.000000047

3 905 951 579

305 324

6

2001

11 368 750

0.39

52 122

919

0.00071

0.000000032

4 257 689 845

259 812

16.1

2002

11 226 132

0.158

50 480

821

0.00029

0.000000013

4 268 638 012

238 400

6.4

2003

11 397 080

0.075

50 329

583

0.00213

0.000000097

4 324 840 581

217 667

3.3

2004

11 716 661

0.03

51 939

604

0.00054

0.000000024

4 480 756 553

212 894

1.3

2005

11 873 588

0.056

54 416

691

0.00158

0.000000072

4 545 142 236

242 849

0.9

2006

11 562 015

0.174

54 348

695

0.00487

0.000000222

4 457 179 375

258 750

2.8

2007

13 223 453

0.029

53 997

680

0.00082

0.000000038

5 322 484 423

263 782

0.5

2008

13 771 403

0.046

50 882

520

0.00131

0.000000059

5 361 502 095

274 966

3.0

2009

12 444 220

0.06

49 804

473

0.0018

8.00E-08

4 824 405 725

312 627

1.0

2010

12 581 242

0.09

50 048

557

0.0017

8.00E-08

4 800 873 166

316 645

2.8

2011

12 283 631

1.59

51 475

899

0.0017

8.00E-08

4 725 836 624

377 017

3.4

2012

12 439 250

0.17

50 439

822

0.0023

8.00E-08

4 797 865 506

391 683

3.4

Reporting year

TABLES 60

EMISSIONS TO THE AIR (TONNes)

TABLE

25

EMISSIONS TO the AIR BY SOURCE (TONNes)

Source

2002

2003

2004

6.39

11.70

2005

2006

2007

2008

2009

2010

2011

2012

Other sources Emissions nmVOC

24.20

Emissions SOx

0.14

6.56

Emissions NOx

73.20

164.00

Emissions CO2

65 491

7 498

45.30

23.70

8.74

Emissions CH4

7.43

0.97

Emissions SOx

33.20

Emissions NOx

420

Emissions CO2

211

809

685

1 363

1 137

49

92

581

537

1 635

2 559

185

0

0

0

151

63

15

0

2 471

76 603

106 978

91 028

113 691

100 019

62 058

13.70

29.50

9

23

20

85

30

25

0.81

2.94

4.48

2

1

3

8

3

9

16.60

5.97

4.58

14.20

1

11

12

47

60

13

76

51

162

256

117

78

160

470

168

146

114 015

31 658

15 557

40 519

68 001

30 990

32 778

46 011

152 940

55 619

59 745

143.00

26.10

25.60

25.90

24.40

2 074

236

92

73

76

75

Tables

Emissions CH4

Well testing Emissions nmVOC

Flaring Emissions nmVOC Emissions CH4

392

104

103

104

97

3 879

827

321

263

278

267

Emissions SOx

3.14

2.41

2.91

3.67

3.23

12

3

3

3

224

215

Emissions NOx

5 124

5 225

5 101

5 202

4 787

3 472

979

607

606

589

556

Emissions CO2

1 110 163

1 058 889

1 081 363

1 094 076

993 153

2 317 829

2 514 504

1 438 349

1 379 989

1 319 289

1 199 498

Emissions nmVOC

11.00

8.79

25.50

40.20

28.70

194

11

17

21

37

33

Emissions CH4

99.90

110.00

142.00

117.00

102.00

68

80

22

37

32

31

Emissions SOx

0.81

11.70

6.67

14.00

8.80

3.87

10.40

26.30

11.54

23.36

26.70

Boilers

Emissions NOx

176

323

387

349

246

85

250

78

95

195

155

Emissions CO2

139 211

150 922

186 992

206 064

177 279

122 527

196 580

152 171

156 106

152 706

242 413

Engines Emissions nmVOC

957

766

771

976

1 024

1 048

1 049

1 217

1 283

1 554

1 487

Emissions CH4

22.80

39.50

39.50

36.20

29.00

29

30

19

16

14

15

Emissions SOx

614

380

399

507

498

491

389

320

387

488

412

Emissions NOx

13 750

11 629

11 631

14 437

14 503

14 639

14 663

16 302

16 822

19 980

19 494

Emissions CO2

704 255

599 555

607 433

722 703

734 423

752 988

764 384

823 882

856 490

1 025 526

989 393

Turbines Emissions nmVOC Emissions CH4

890

881

922

919

888

905

898

883

890

867

883

3 447

3 345

3 498

3 488

3 377

3 450

3 418

3 354

3 692

3 563

3 653

Emissions SOx

170

173

184

162

171

173

106

112

108

105

156

Emissions NOx

31 009

33 003

34 605

34 266

34 557

35 083

34 590

32 506

31 993

30 528

30 088

Emissions CO2

9 158 488

9 490 564

9 817 817

9 810 225

9 586 688

9 922 517 10 156 180

9 892 780

9 922 026

9 630 473

9 885 826 61

TABLE

26

EMISSIONS of CH4 AND nmVOC FROM DIFFUSE Sources AND COLD VENTING (TONNes)

Reporting year

nmVOC emissions

CH4 emissions

1997

5 514

9 728

1998

4 998

1999

Reporting year

TABLES

nmVOC emissions

CH4 emissions

2005

7 411

14 410

10 471

2006

6 617

14 057

3 933

7 489

2007

7 701

14 935

2000

4 930

10 339

2008

9 114

19 023

2001

5 272

12 195

2009

9 161

18 483

2002

5 435

12 809

2010

7 186

18 068

2003

7 208

13 804

2011

8 254

19 181

2004

7 555

14 456

2012

10 083

18 267

TABLE

27

EMISSIONS of CH4 AND nmVOC FROM STORAGE AND LOADING (tonNes)

Type

2002

2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

24 607

11 683

9 971

6 163

4 251

2 099

3 578

6 397

4 607

4 041

2 978

1 307

496

1 024

465

580

119

332

998

308

596

337

189 991

151 696

122 137

78 000

66 677

61 954

34 714

27 032

21 483

15 072

17 409

15 639

13 754

13 572

10 650

7 940

7 521

6 631

5 890

4 017

2 711

2 894

storage Emissions nmVOC Emissions CH4

loading Emissions nmVOC Emissions CH4

62

TABLE

28

EMISSIONS from WELL TESTING

Combusted gas (cu.m)

Combusted oil (tonnes)

Combusted diesel (tonnes)

Combusted gas (cu.m)

Combusted oil (tonnes)

1997

0

11 707 758

29 697

2005

103

12 245 846

3 840

1998

325

19 296 566

22 527

2006

43

18 662 837

8 558

1999

1 336

12 086 301

16 498

2007

0

8 304 214

2 469

2000

34 844

7 186 823

12 076

2008

0

4 442 709

6 997

2001

325

26 310 306

32 142

2009

15

11 509 318

6 301

2002

366

30 950 368

12 792

2010

48

31 426 218

24 947

2003

9

3 639 428

7 128

2011

88

6 046 803

7 483

2004

1 164

3 363 520

1 461

2012

0

8 560 987

10 891

TABLE

29

Reporting year

Tables

Combusted diesel (tonnes)

Reporting year

SEPARATED WASTE BY SOURCE (tonNes)

Other

Blasting sand

EE waste

1997

Glass

Food contaminated

Metal

Paper

Cardboard (brown paper)

Plastic

Residual waste

Wood

Wet organic waste

27

156

5 029

246

214

6

4 526

440

5

1998

1

17

913

8 374

161

587

66

8 757

992

6

1999

10

44

934

7 210

224

709

121

6 234

1 207

130

2000

113

61

1 119

6 577

617

514

135

6 568

1 258

131

2001

243

92

1 200

9 043

637

696

234

6 742

1 346

106

2002

189

67

1 301

5 665

694

575

232

5 565

1 372

142

2003

225

81

1 051

6 797

754

295

300

4 426

1 327

142

2004

291

74

1 236

5 179

564

443

274

4 008

1 209

95

2005

943

36

404

89

1 303

6 932

640

500

306

4 217

1 442

137

2006

4669

15

461

105

1 464

9 305

1 497

443

337

3 707

1 620

161

2007

1728

0

638

103

1 922

8 487

700

521

457

3 381

1 895

206

2008

6094

3

625

85

2 026

8 787

809

433

422

3 132

1 891

143

2009

951

0

530

98

2 198

8 945

828

414

490

3 079

1 855

120

2010

4747

1

590

94

2 622

9 059

926

440

597

3 718

2 385

107

2011

5425

3

773

115

2 781

9 432

980

483

635

3 750

2 604

89

2012

7043

0

692

115

3 390

11 180

1 100

457

676

2 586

2 338

115

63

TABLE

30

HAZARDOUS WASTE (TONNes)

Water type Drilling waste and other Batteries

1997

1998

1999

2000

2001

2002

24 501

32 649

19 722

54 624

45 062

32 674

83.6

79.7

27.7

62.1

59.1

73.3

12.1

22.2

182.0

Blasting sand

TABLES

Mixed chemicals w/halogen

72

929

8 432

20 174

33 326

Mixed chemicals w/metal

3.2

0.6

4.4

12.3

4.4

Mixed chemicals wo/halogen or heavy metals

95.4

392

303

93.2

820

111

Lightbulbs

14.9

21.3

25.1

29.4

37.6

38.4

Paint

133

121

76

205

230

362

2 304

2 894

1 944

1 882

2 192

2 967

Oil-contaminated waste

64

Pure chemicals w/halogen

0.3

59.4

1.1

1.9

0.8

Pure chemicals w/heavy metals

0.7

1.1

0.6

0.9

3.2

Pure chemicals wo/halogen or heavy metals

83.3

36.8

180

211

101

Spray cans

26.7

7.8

9.4

11.4

10.6

4.4

2004

2005

2006

2007

2008

2009

2010

2011

2012

70 664

101 939

94 679

103 894

119 576

142 142

151 704

258 482

308 456

305 669

77.0

95.7

119.0

118.0

149.0

40.7

32.8

35.6

50.3

32.2

47.4

95.1

130.0

52.1

73.4

61.0

29.4

41.4

72.5

248.0

6 661

1 354

12 081

7 593

5 341

118

381

916

5 084

6 978

10.1

4.4

9.2

6.4

37.4

0.7

0.3

0.2

0.3

0.2

139

163

387

137

170

69

54

28

30

119

36.9

25.3

37.3

27.7

33.8

8.5

6.0

4.1

5.6

8.5

350

282

451

433

289

139

67

164

83

159

1 673

1 815

3 098

3 220

3 876

1 256

1 218

1 088

1 966

1 291

0.6

3.8

1.4

442

11

43

6

0

0

0

1.3

12.1

15.5

28.6

16.4

10.8

12.2

4.7

2.8

7.6

94.8

87

240

102

123

35

34

6

17

7

5.5

11.9

14.9

18.8

23.1

2.5

3.6

3.3

5.2

2.3

Tables

2003

65

9

terms and abbreviations

CH4 Methane Carbon dioxide CO2 nmVOC non-methane

volatile organic

compounds nitrogen oxides NOx sulphur oxides SOx sulphur dioxide SO2

b/d oe scm

barrels per day oil equivalent standard cubic metres

BAT Best available technology.

IOR Improved oil recovery.

Klif Norwegian Climate and Pollution Agency (previously the Norwegian Pollution Control Authority).

NCS Norwegian continental shelf.

NPD Norwegian Petroleum Directorate.

OGP International Association of Oil and Gas Producers.

66

Ospar Oslo-Paris convention for the protection of the marine environment of the north-east Atlantic.

Fifteen countries with coasts on or rivers emptying into these waters are signatories.

Plonor â&#x20AC;&#x153;Pose little or no risk to the marine environmentâ&#x20AC;?, a list from Ospar of chemical compounds considered to have little or no impact on the marine environment if discharged.

Conversion factors based on the energy content in hydrocarbons. Calculated in accordance with definitions from the NPD.

Oil 1 cu.m = 1 scm oe Oil 1 barrel = 0.159 scm Condensate 1 tonne = 1.3 scm oe Gas 1 000 scm = 1 scm oe NGL 1 tonne = 1.9 scm oe

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