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T 2013

The environmenTal efforTs of The oil and gas indusTrywith facts and figures

environmenTal reporT

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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).

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emissions To The air 26

discharges To The sea 12

offshore operaTionsand The marine environmenT 22

level of acTiviTyon The ncs 08

wasTe 40

foreword 04

Tables 44

summary 06

Terms and abbreviaTions 66

6.1 Emission sources. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 276.2 Emissions of greenhouse gases . . . . . 286.3 Short-lived climate forcers . . . . . . . . . . . 296.4 Emissions of CO2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 306.5 Greenhouse gas emissions . . . . . . . . . . . . . . . . .

from Norwegian and international . . .

petroleum operations . . . . . . . . . . . . . . . . . . . . . 326.6 Power from shore . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 346.7 Emissions of NOx . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 356.8 The NOx agreement and . . . . . . . . . . . . . . . . . . . . . . .

international obligations . . . . . . . . . . . . . . . 366.9 Emissions of nmVOC . . . . . . . . . . . . . . . . . . . . . . . . 376.10 Emissions of CH4 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 386.11 Emissions of SOx . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 39

4.1 Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 134.2 Produced water. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 144.3 Chemicals . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 164.4 Discharges of oil . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 194.5 Acute spills . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20

5.1 Water-column monitoring . . . . . . . . . . . . 245.2 Sediment monitoring . . . . . . . . . . . . . . . . . . . . . . . 25

The environmenTal efforTs of The oil and gas indusTrywith facts and figures

environmenTal reporT

1 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.

foreword

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Emission/discharge reporting by the operator companies complies with government require-ments 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 opera-tional 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 dis-charges 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 environ-mental monitoring.

All fields with production facilities on the NCS are included. Emissions/discharges from the construc-tion 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.

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.

2 greenhouse gas emissions from oil and gas acTiviTies are relaTively sTable, buT subsTanTially lower Than The forecasTs prepared a few years ago.

summary

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Good progress with discoveries and persis-tently 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 promis- ing 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 discov-eries, overall petroleum production is again expected to be able to rise some-what 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 emis-sions 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 asso-ciations on reducing their overall NOx emissions. The fund model established

by this deal ensures that emission reduc-tions 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 invest-ment 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 substan-tial 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 environ-mental authorities concluded in 2006 that the industry had reached the target of zero hazardous discharges for chemical addi-tives set in 1997. Such discharges have now stabilised at this low level. The decline in acute discharges seen over the past five

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 environ-mental 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 govern-ment’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 self-renewal 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 effi-ciency in using both chemicals and energy.

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.

370 000Tonnes in reduced annual emissions of carbon equivalenT from 2015 as a resulT of nox projecTs

99.8 % 410reducTion in red and black chemicals

per Tonne – carbon Tax for The peTroleum indusTry from 2013

NOK

3The oil and gas indusTry has compleTed anoTher year wiTh a high level of acTiviTy on The ncs.

level of acTiviTy on The ncs

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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 OutProduction 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/dHowever, 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 salesThe 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.

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 gOOdThe 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.

resOurce base upgradedThe 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.

activity high On the ncsAccording 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 develop-ments and producing fields, while explora-tion, 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 petro-leum sector thereby confirms its role as the most important engine driving the Norwegian economy.

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.

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new acreage still impOrtantThe 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 compa-nies, of which 107 received two or nomi-nations. A record 181 blocks were nomi-nated for the Barents Sea. At the deadline of 4 December 2012, the ministry had received applications from 36 companies.

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

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 manage-ment plan for this part of the NCS. The deadline for applications is 11 September 2013, and plans call for new licences to be

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 inter-pretations.

Source: NPD Source: Statistics Norway

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peTroleum producTion by regionMillion scM oe

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invesTmenT in The oil secTor by caTegory (noK bn)

north sea field development

land-based operations

norwegian sea Producing fields

exploration and conceptual studies

barents sea Pipeline transport

estimate for 2013 from statistics norway’s investment survey for the oil industry, first quarter 2013.

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1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

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resource growth overall petroleum production

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ncs resource growTh and producTion Million scM oe

4boTh operaTional and acuTe discharges To The sea from oil and gas operaTions on The ncs are declining.

discharges To The sea

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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 bore-hole 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.

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

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

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 moni-toring. 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.

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.

4.1 drilling

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injecTion of drill cuTTings conTaminaTed wiTh oil-based drilling fluids (tonnes)

injecTion of drill cuTTings when drilling wiTh waTer-based fluids (tonnes)

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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.

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.

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.

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 environ-mental impact can be identified from discharging 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.

4.2 produced waTer

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discharges and injecTion of produced waTer (Million cubic Metres)

Produced water discharged Produced water injected

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average oil concenTraTion in produced waTer (Mg/l)

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raTio beTween produced waTer and oil

regulatory requirement Produced water/oilconcentration (mg/l) of dispersed oil in produced water

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A dedicated flow diagram has been devel-oped for environmentally hazardous sub-stances 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 condi-tions.

2) yellow Chemicals in use, but not covered by any of the other categories. Can normally be discharged without specified conditions.

3) red Chemicals which are environ-mentally 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.

The operators have worked purposefully to replace chemicals which have poor envi-ronmental properties with more environ-mentally 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 dis-charges were slightly higher in 2012 than the year before because of tests with fire-extinguishing 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 con-sidered 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 risk-based 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 self-renewal.

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).

4.3 chemicals

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chemical discharges broken down by klif’s colour coding (2012)

0.0016%

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substances on ospar’s Plonor list green

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1.1 black

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 in yellow category:

substances covered by reach annexes iV and V 6 99 Yellow

substances with biodegradability > 60% 100 Yellow

substances with biodegradability 20-60%

sub-category 1: expected to biodegrade fully

101 Yellow

sub-category 2: expected to biodegrade to environ-mentally non-hazardous substances

102 Yellow

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

102 Yellow

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hisTorical developmenT of green, yellow, red and black chemical discharges (tonnes)

klif’s Table

green chemicals Yellow chemicals red chemicals black chemicals

1 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.

2 Removed from the black category in the activities regulations.

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.

4 Data for degradability and bio- accumulation must accord with

approved tests for offshore chemicals.

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.

klif’s colourcategory

klif’s colourcategorycategory1 category1discharge discharge

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■ Produced water: water which has been in contact with the geological forma-tions 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 dis-

charge, it will contain minor residues of oil/condensate as well as dissolved substances.

■ 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.

■ 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.

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.

4.4 discharges of oil

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hisTorical developmenT of oil discharges To The sea from various sources (tonnes)

the marked peak in 2007 reflects the acute spill of about 4 700 scm from the statfjord loading buoy.

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operational discharges of oily water from petroleum activities on the ncs have three principal sources.

dispersed oil in produced water

acute spillsdisplacement, drain and jetting water

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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

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 envi-ronmental 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.

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.

4.5 acuTe spills

the Kristin platform.

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ToTal acuTe oil spills on The ncs

ToTal volume of acuTe spills broken down by oil and chemicals (cu.M)

acuTe chemical spills on The ncs

12 14chemicals are mainly drill cuttings.

chemicals oil

total exceeding 50 litres total acute spills

5environmenTal moniToring involves The sysTemaTic collecTion of daTa using verifiable meThods. The goal is To documenT The condiTion of The marine environmenT and iTs developmenT.

offshore operaTions and The marine environmenT

23

Monitoring is conducted by independent and qualified consultants in accordance with government requirements and stand-ards. 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 docu-ment the condition of the marine environ-ment 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 phys-ical 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 petro-leum 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 petro-leum-related activities (2002-15) (Proof and Proofny) in the Oceans and Coastal Areas programme at the Research Council of Norway has contributed much new know- ledge about the significance of discharges from offshore petroleum operations. Sixty-five 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:

■ Nothing suggests that Arctic and sub-Arctic marine organisms are more vulner-able to discharges than similar life forms found elsewhere on the NCS.

■ Environmental monitoring results have reduced concerns about the effect of oil-polluted 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 main-tain 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.

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.

24

impact mOnitOringMonitoring 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

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 investiga-tion 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 bioaccumu-lation occurs in these organisms.

cOnditiOn mOnitOringSuch 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 con-tribute to PAH levels in the North Sea. This could be one of the topics addressed in the 2014 condition monitoring study.

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.

5.1 waTer-column moniToring

25

Before any field is brought on stream, an investigation must be conducted to estab-lish the base condition. Each region and field is investigated every third year to establish the physical, chemical and biolog-ical condition of the sediments. The moni-toring is conducted by independent accred-ited consultants, and detailed guidelines ensure that results from different surveys are comparable across time and space. These results are assessed by the govern-ment’s panel of experts, and made avail-able 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 pro-gramme 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 com-pleted, 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 THC- contaminated 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.

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.

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.

5.2 sedimenT moniToring

6 emissions To The airpower generaTion fuelled by naTural gas or diesel oil is The main source of carbon and nox emissions.

27

emissiOn sOurces

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 con-

nection with well testing and well maintenance.

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 emis-sions 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 permit-ted 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.

SOx emissions primarily derive from the combustion of sulphur-containing hydro-carbons. 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

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 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.

6.1 emission sources

fig

ur

e

emissions To The air on The ncs compared wiTh The inTernaTional average

100 Kg Per scMoe Produced

Kg Per scMoe Produced

1.2

1.0

0.8

0.6

0.4

0.2

0.0

co2 nox ch4 so2nmVoc

Source: OGP and Environment Web15

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

international average for oil-producing countries 2011

28

15

14

13

12

11

10

0

2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

The first legally binding climate agreement was negotiated at Kyoto in Japan in 1997. This protocol requires that the industrial-ised countries collectively cut their green-house 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.

The 2011 climate summit at Durban in South Africa agreed in extra time on a road map towards a new global climate agree-ment 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.

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

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.

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.

6.2 emissions of greenhouse gases

fig

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emissions of carbon equivalenT on The ncs Million tonnes16

29

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

On that basis, Klif implemented a project on evaluating flaring strategy, techniques to reduce flaring and its emissions, emis-sion 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:

■ current flaring systems/technology and criteria for selecting these

■ emission of NOx, CO2, SO2, methane, nmVOCs and particles

■ 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 emis-sions of greenhouse gases and other compo-nents. The companies have contributed to the project with extensive information from their own operations.

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.

6.3 shorT-lived climaTe forcers

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.

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.

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

30

17

2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

Figure 17 shows carbon emissions from operations on the NCS and the distribu-tion 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

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.

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 re-duce 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 – as also estimated by the Climate Cure (2010) – 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 substan-tially 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 main-taining low emissions per unit produced.

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.

6.4 emissions of co2

fig

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direcT carbon emissions (Million tonnes) and by source

breakdown by source 2012

mill

Ton

ne

s

14.0

12.0

10.0

8.0

6.0

4.0

2.0

0.0

79.4%

9.6%

7.9%

Turbines

flare

engines

boilerswell TesTing

1.9%

1.0%

12.4

31

2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

60

50

40

30

20

10

0

2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

600

500

400

300

200

100

0

18

fig

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specific carbon emissions (Kg/scM oe) 19

Platforms on sleipner east.

fig

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flare gas consumpTion and associaTed calculaTed carbon emissions

3.0

2.5

2.0

1.5

1.0

0.5

0

emissions (mill tonnes)flared gas (mill scm)

32

50

40

30

20

10

0

1

32

8

5

4

67

2003 2004 2005 2006 2007 2008 2009 2010 2011

from norwegian and inTernaTional peTroleum operaTions

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, Norway’s participation in the EU emis-sion trading market, flaring provisions in the Petroleum Activities Act, the require-ment 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 energy-efficient production and low carbon emis-

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 emis-sions 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 re-covering their remaining reserves is energy-

intensive. Norway’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 allow-ances will be harmonised with the EU regu-lations 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 govern-ment 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.

The oil and gas industry accounts for about a quarter of norway’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.

6.5 greenhouse gas emissions

fig

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greenhouse gas emissions per uniT produced in various peTroleum provinces(kg of carbon equivalenT per barrel of oe produced)

norway south americaMiddle east1 2 3 4 6 7 85 north americaeurope asia/australasiarussia (fsu) africa

Source: OGP and Environment Web

20

33

34

hammerfest lng, Melkøya.

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 installa- tions on the Utsira High (Johan Sverdrup, Edvard Grieg, Ivar Aasen and Dagny).

Transmitting power from shore to NCS installations is much discussed as an emis-sion-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 devel-opments 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 exist-ing 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 govern-ment stated that it aims to increase the use of power from shore. Decisions on electricity supply are conditional on sufficient addi-tional power and grid capacity being avail-able 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 produc-tion 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.

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.

6.6 power from shore

35

50 439

03 04 05 06 07 08 09 10 11 12

59%

39%

22

2155 000

50 000

45 000

40 000

0

2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

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 break-down by source is now stable.

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

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 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.

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.

6.7 emissions of nox

fig

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nox emissions per hydro-carbon delivered (Kg/scM oe)

0.30

0.25

0.20

0.15

0.10

0.05

0.0

fig

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overall nox emissions (tonnes) and by source

breakdown by source 2012

flare well TesTing

Turbines

engines

1% 1%

Ton

ne

s

36

23

35%

13% 14%

12%

12%

11%

3%

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.

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.

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

The fund model in this environmental agree-ment ensures that emission reductions are implemented where they yield the biggest environmental return per krone spent. Projects implemented had achieved veri-fied NOx emission reductions by the dead-lines specified which have so far met the

commitments in both first and second agreement periods. This scheme makes an important contribution to Norway’s observance of the Gothenburg protocol.

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 cata-lytic converters to treat emissions with urea and the installation of fuel-efficient

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

The environmental agreement on nox regulates the commitments made to the government by norway’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.

6.8 The nox agreemenT and inTernaTional obligaTions

see: annual report of the nox fund for 2012

fig

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breakdown of emission reducTions by secTor for measures supporTed by The nox fund so far (2012)

offshore service ships

fishing boaTsferries/

land-based

cargo carriers

passenger ships

indusTry

Tankers

offshore

rigs

37

200 000

150 000

100 000

50 000

0

24

2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

33 021

53%18%

9%

8%

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.

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 imple-mented on storage ships and shuttle tankers. Cold venting and diffuse emissions account for the bulk of the remainder.

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 Norway’s opportunities for fulfilling its commitments under the Gothenburg protocol.

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.

6.9 emissions of nmvoc

fig

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ToTal emissions of nmvoc (tonnes) and by source

breakdown by source 2012

Ton

ne

s

loading

sTorage

oTher sources

diffuse emissions

and cold venTing

38

25

2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

40 000

35 000

30 000

25 000

20 000

15 000

10 000

5 000

0

25 658

71%

11%

16%

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.

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.

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.

6.10 emissions of ch4

fig

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ToTal emissions of ch4 (tonnes) and by source

breakdown by source 2012

sTorage

loading

oTher sources

diffuse emissions

and cold venTing

Ton

ne

s

1%

the oseberg c platform.

39

1 000

800

600

400

200

0

26

2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

822

Figure 26 shows SOx emissions from oper-ations on the NCS and by source in 2012. Total emissions in that year came to 822 tonnes, down from 2011.

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.

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.

6.11 emissions of sox

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overall emissions of sox (tonnes) and by source

breakdown by source 2012

boilerswell TesTing

Turbines

flare 50.1%26.1%

19.0%

engines

Ton

ne

s

3.2% 1.5%

the aker barents drilling rig.

7 wasTenorwegian oil and gas has developed iTs own guidelines for wasTe managemenT in The offshore secTor.

41

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

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.

fig

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breakdown of non-hazardous wasTe from The offshore indusTry (2012) 27

0.4%

2.3%

2.3%

0.0%

0.4%

1.5%

3.7%

plasTic

abrasive sandbrown paper

paper

meTals

food-conTaminaTed wasTe

oTher

wood

residual wasTe

37.7%

23.7%

11.4%

7.9%

8.7%

weT organic wasTe

elecTronic wasTe

elecTrical and

glass

42

300 000

250 000

200 000

150 000

100 000

50 000

0

2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

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.

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 – which contributed to a big increase in the volume of drilling waste.

Injection provides substantial environ-mental 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

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.

lOw-level radiOactive wasteThe rocks from which oil and gas are pro-duced contain a number of minerals and metals, some of which are weakly radio-active. 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 speci-fied 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.

fig

ur

e

oil-conTaminaTed wasTe senT ashore, volume developmenTs (tonnes)28

drilling mud and cuttings oil emulsions

43

8 Tables

01

02

45

Tab

les

reporting year net oil gross oil net gas gross gasnet

condensategross

condensatenet 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 122 668 113 335 99 231 141 269 4 180 17 276 16 022

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

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

Tab

leTa

ble

hisTorical producTion daTa for oil, condensaTe, gas and waTer (Mill SCM, GAS bN SCM)

injecTion daTa (SCM)

03

04

05

46

TAB

LES

reporting yearDrilling fluids consumption

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

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

reporting yearDrilling fluids consumption

Drilling fluids discharged (volume)

Drilling fluids injected

Drilling fluids Transported to land

base fluids left in hole or lost

to formation

2004 2 298 826 0 439 1 030

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

reporting yearDrilling fluids consumption

Drilling fluids discharged (volume)

Drilling fluids injected

Drilling fluids Transported to land

base fluids left in hole or lost

to formation

2004 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

Tab

le

drilling wiTh oil-based drilling fluids (TONNES)

Tab

le

drilling wiTh synTheTic drilling fluids (TONNES)

Tab

le

drilling wiTh waTer-based drilling fluids (TONNES)

06

07

08

47

Tab

les

reporting yearCuttings exported

to other fields Cuttings

discharged to sea Cuttings

volume injectedCuttings

Transported to landTotal amount

generated cuttings/mud

2003 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

2006 0 0 54 433 22 679 211 942

2007 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

2011 0 0 19 699 68 190 64 614

2012 0 0 23 409 65 689 93 141

reporting yearCuttings exported

to other fields Cuttings

discharged to sea Cuttings

volume injectedCuttings

Transported to land

2004 86 061 1 726 58

2005 72 684 895 893

2006 325 80 757 1 423 2 226

2007 0 86 405 1 191 722

2008 651 70 199 2 717 2 501

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

reporting year oil-based

1997 766

1998 1 926

1999 0

2000 852

2001 5 926

2002 0

2003 5 600

2004 0

reporting year oil-based

2005 3 268

2006 2 383

2007 1 668

2008 3 692

2009 7 579

2010 14 994

2011 91

2012 0

Tab

le

disposal of cuTTings from drilling wiTh oil-based drilling fluids (TONNES)

Tab

leTa

ble

disposal of cuTTings from drilling wiTh waTer-based fluids (TONNES)

ToTal amounT of cuTTings/mud imporTed To fields(TONNES)

09

10

11

48

TAB

LES

substance 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

others 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

Phenols 184 168 206 962 170 118 179 405 212 822 207 560 185 041 166 660 179 546 206 564

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

organic acids 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

substance 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

benzene 446 233 682 490 683 080 771 347 871 200 862 411 868 175 832 031 771 333 848 713

ethylbenzene 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

substance 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

lead 527 273 173 348 255 386 290 239 428 309

iron 714 214 888 912 1 108 015 1 370 415 1 008 440 1 058 121 797 369 825 822 959 698 863 198

cadmium 32 20 11 30 28 41 28 22 32 18

copper 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

nickel 407 452 1 073 735 299 299 142 200 223 198

Zinc 11 211 7 130 2 253 9 129 9 847 16 651 7 100 6 948 10 108 5 418

Tab

leTa

ble

Tab

le

selecTed groups of organic compounds DiSCHARGE iN PRODUCED WATER (KG)

bTx compounds DiSCHARGE iN PRODUCED WATER (KG)

heavy meTals DiSCHARGE iN PRODUCED WATER (KG)

12

13

49

Tab

les

substance 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

butyric acid 644 737 755 601 709 758 752 861 671 281 777 200 714 602 627 237 519 296 453 964 456 609

acetic acid 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

formic acid 65 731 152 368 209 953 159 966 501 911 449 707 314 221 563 669 493 913 450 016 341 274

naphthenic acid 259 322 262 712 283 637 250 405 264 051 179 185 99 691 96 547

Valeric acid 256 215 298 361 312 267 336 195 344 439 374 276 341 590 338 214 241 354 159 998 165 674

Propionic acid 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

substance 2003 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

Phenols 184 168 206 962 170 118 179 405 212 822 207 560 185 041 166 660 179 546 206 564

Tab

leTa

ble

phenols DiSCHARGE iN PRODUCED WATER (KG)

organic acids DiSCHARGE iN PRODUCED WATER (KG)

14

50

TAB

LES

substance 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

c1-naphthalene 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

c2-naphthalen 20 667 26 021 25 248 27 251 21 143 16 086 19 636 24 669 21 880 26 936 27 707

c3-dibenzothiophene 9 191 119 263 474 342 71 92 20 22 27 26

c3-Phenanthrene 737 517 635 466 187 375 306 662 694 1 157 1 111

c3-naphthalene 11 453 18 227 17 359 21 957 11 226 7 813 11 614 21 719 17 219 22 363 23 230

dibenz(a,h)anthracene* 8 10 7 9 12 3 4 3 2 3 2

dibenzothiophen 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

fluorene* 1 200 1 683 1 620 1 769 1 308 1 132 1 166 1 175 1 126 1 384 1 327

indeno(1,2,3-c,d)pyrene* 6 6 4 5 12 2 3 2 1 1 2

chrysene* 68 43 57 74 61 40 61 42 30 41 38

naphthalene 43 622 40 545 57 243 39 133 63 073 49 450 44 963 48 175 47 770 45 492 48 816

Pyrene* 52 116 97 117 64 64 74 49 43 34 42

* included in the ePa-16 total

Tab

le

pah compounds DiSCHARGE iN PRODUCED WATER (KG)

15

16

51

Tab

les

klif colour category

reportingyear 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

greendischarge 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

Yellowdischarge 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

reddischarge 626 299 93 39 23 15 32 16 8 8

consumption 7 661 7 852 6 375 5 659 5 376 4 261 3 206 2 894 1 842 2 088

blackdischarge 5 2 3 3 1 2 1 1 1 2**

consumption 218 211 121 40 50 60 16 1 259* 1 140* 746**

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

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.

Tab

leTa

ble

discharge and consumpTion of chemicals by klif colour caTegory (TONNES)

discharge of chemicals by klif colour caTegory (TONNES)

17

52

TAB

LES

water type 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

drainage

oil index volume to sea (tonnes) 9 7 16 9 8 10 6 8 7.85 8

dispersed oil volume to sea (tonnes) 21 13 11 32 13 2 0 0 0 0

water volume to sea (cu.m) 1 390 614 711 201 663 964 1 148 995 902 487 905 396 953 964 917 986 727 811 867 531 953 596

total water volume (cu.m) 1 437 979 818 045 722 460 1 200 245 979 867 962 543 993 156 1 099 819 763 736 891 951 979 802

injected water volume (cu.m) 47 296 106 817 57 186 51 515 77 086 53 328 36 298 184 247 19 875 16 740 18 831

displacemenT

oil index volume to sea (tonnes) 73 113 76 78 94 58 55 47 50.5 58

dispersed oil volume to sea (tonnes) 255 146 158 119 133 0 0 0 0

water volume to sea (cu.m) 60 218 998 56 862 577 53 326 642 47 403 128 41 633 651 42 080 398 35 781 227 31 567 044 31 953 823 27 025 783 31 491 555

total water volume (cu.m) 60 218 998 56 850 991 53 326 642 47 403 128 41 633 651 42 080 398 35 781 227 31 567 050 31 953 823 27 025 783 31 491 555

injected water volume (cu.m) 0 0 0 0 0

jeTTing

oil index volume to sea (tonnes) 32 42 67 15 26 13 24 65 53.1 43

dispersed oil volume to sea (tonnes) 8 61 3 31 25

water volume to sea (cu.m)

total water volume (cu.m)

injected water volume (cu.m)

produced

oil index volume to sea (tonnes) 1 474 1 511 1 510 1 308 1 532 1 569 1 487 1 443 1 478 1 535

dispersed oil volume to sea (tonnes) 2 572 2 276 2 293 2 871 2 441

water volume to sea (cu.m) 118 932 533 134 729 541 142 803 237 147 269 373 144 741 847 161 825 645 149 241 700 134 770 215 130 842 793 128 550 571 130 909 973

total water volume (cu.m) 136 323 268 156 391 243 173 892 780 177 388 172 173 349 396 182 807 754 173 375 110 158 559 726 157 890 256 160 758 982 162 958 696

injected water volume (cu.m) 16 636 832 21 286 897 29 794 046 32 569 423 31 693 056 26 665 258 30 379 135 29 547 450 33 217 136 31 095 328 32 756 572

Tab

le

discharge of oil-conTaminaTed waTer

53

Tab

les

water type 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

drainage

oil index volume to sea (tonnes) 9 7 16 9 8 10 6 8 7.85 8

dispersed oil volume to sea (tonnes) 21 13 11 32 13 2 0 0 0 0

water volume to sea (cu.m) 1 390 614 711 201 663 964 1 148 995 902 487 905 396 953 964 917 986 727 811 867 531 953 596

total water volume (cu.m) 1 437 979 818 045 722 460 1 200 245 979 867 962 543 993 156 1 099 819 763 736 891 951 979 802

injected water volume (cu.m) 47 296 106 817 57 186 51 515 77 086 53 328 36 298 184 247 19 875 16 740 18 831

displacemenT

oil index volume to sea (tonnes) 73 113 76 78 94 58 55 47 50.5 58

dispersed oil volume to sea (tonnes) 255 146 158 119 133 0 0 0 0

water volume to sea (cu.m) 60 218 998 56 862 577 53 326 642 47 403 128 41 633 651 42 080 398 35 781 227 31 567 044 31 953 823 27 025 783 31 491 555

total water volume (cu.m) 60 218 998 56 850 991 53 326 642 47 403 128 41 633 651 42 080 398 35 781 227 31 567 050 31 953 823 27 025 783 31 491 555

injected water volume (cu.m) 0 0 0 0 0

jeTTing

oil index volume to sea (tonnes) 32 42 67 15 26 13 24 65 53.1 43

dispersed oil volume to sea (tonnes) 8 61 3 31 25

water volume to sea (cu.m)

total water volume (cu.m)

injected water volume (cu.m)

produced

oil index volume to sea (tonnes) 1 474 1 511 1 510 1 308 1 532 1 569 1 487 1 443 1 478 1 535

dispersed oil volume to sea (tonnes) 2 572 2 276 2 293 2 871 2 441

water volume to sea (cu.m) 118 932 533 134 729 541 142 803 237 147 269 373 144 741 847 161 825 645 149 241 700 134 770 215 130 842 793 128 550 571 130 909 973

total water volume (cu.m) 136 323 268 156 391 243 173 892 780 177 388 172 173 349 396 182 807 754 173 375 110 158 559 726 157 890 256 160 758 982 162 958 696

injected water volume (cu.m) 16 636 832 21 286 897 29 794 046 32 569 423 31 693 056 26 665 258 30 379 135 29 547 450 33 217 136 31 095 328 32 756 572

18

54

TAB

LES

application 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

drilling and well

chemicals

discharged 143 237 103 226 74 379 63 116 72 641 87 682 90 841 137 008 104 966 111 839 112 391

injected 89 406 80 993 82 800 80 640 79 872 78 166 88 506 65 682 44 204 37 685 36 627

consumed 533 410 335 015 321 131 320 491 323 238 352 533 357 736 402 110 409 337 357 665 373 038

gas processing

chemicals

discharged 10 646 9 733 10 481 10 555 13 062 11 619 13 124 11 849 9 698 11 097 16 079

injected 411 455 3 141 412 1 241 757 1 502 1 634 1 406 1 628 4 133

consumed 14 796 13 466 16 789 14 540 17 760 18 804 22 257 21 381 17 905 21 061 22 563

auxiliary chemicals

discharged 2 566 2 293 2 391 1 919 2 223 3 622 4 031 4 795 4 244 4 489 4 903

injected 162 300 344 403 369 250 810 501 420 377 190

consumed 4 161 3 929 3 525 2 962 3 279 6 269 7 135 7 886 8 091 8 073 7 671

injecTion chemicals

discharged 185 283 1 049 1 335 132 332 235 200 188 212 176

injected 3 332 501 215 687 1 742 1 464 1 486 1 485 1 367 1 492 2 945

consumed 13 441 14 095 14 666 15 115 14 730 15 361 15 517 12 997 11 487 9 830 9 155

chemicals from oTher

producTion locaTions

discharged 9 913 1 259 1 533 1 140 917 697 847 753 753 692 952

injected 153 228 59 41 210 24 117 114 150

consumed 64 338 419 438 434 614 475 536 0 0

chemicals added

To The exporT flow

discharged 9 113 282 188 311 439 1 664 1 847 1 483 1 951

injected 0 0 0 0 0

consumed 14 616 7 032 4 941 7 805 5 866 5 180 5 443 5 085 5 094 4 665 5 269

producTion chemicals

discharged 8 582 11 343 11 722 11 131 14 049 15 317 17 208 17 033 16 001 17 272 19 577

injected 1 579 4 051 3 706 2 995 5 881 3 323 4 046 4 500 4 403 4 598 4 082

consumed 22 013 32 206 26 865 24 405 30 069 29 131 31 278 27 720 26 816 28 564 29 018

reservoir managemenT

discharged 1 3 1 1 2 0 9 5 2 3

injected 0 0 0 0 0 0

consumed 1 3 1 1 1 2 14 12 14 6 4

pipeline chemicals

discharged 1 259 1 746 389 962 1 049 2 015 516 917 1 308 3 245 4 130

injected 17 20 0 146 599 936 494

consumed 1 265 1 898 663 2 159 4 886 5 189 3 385 2 973 2 477 4 609 7 029

ToTal

total discharged 176 398 129 996 101 944 90 441 104 260 121 597 127 240 174 228 139 009 150 332 160 162

total injected 94 890 86 318 90 360 85 385 89 165 84 000 96 560 73 973 52 515 46 829 48 621

total consumed 603 767 407 643 388 919 387 897 400 267 432 904 443 381 480 640 481 756 434 472 453 747

Tab

le

ToTal consumpTion, discharge and injecTion of chemicals by applicaTion (TONNES)

55

Tab

les

application 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

drilling and well

chemicals

discharged 143 237 103 226 74 379 63 116 72 641 87 682 90 841 137 008 104 966 111 839 112 391

injected 89 406 80 993 82 800 80 640 79 872 78 166 88 506 65 682 44 204 37 685 36 627

consumed 533 410 335 015 321 131 320 491 323 238 352 533 357 736 402 110 409 337 357 665 373 038

gas processing

chemicals

discharged 10 646 9 733 10 481 10 555 13 062 11 619 13 124 11 849 9 698 11 097 16 079

injected 411 455 3 141 412 1 241 757 1 502 1 634 1 406 1 628 4 133

consumed 14 796 13 466 16 789 14 540 17 760 18 804 22 257 21 381 17 905 21 061 22 563

auxiliary chemicals

discharged 2 566 2 293 2 391 1 919 2 223 3 622 4 031 4 795 4 244 4 489 4 903

injected 162 300 344 403 369 250 810 501 420 377 190

consumed 4 161 3 929 3 525 2 962 3 279 6 269 7 135 7 886 8 091 8 073 7 671

injecTion chemicals

discharged 185 283 1 049 1 335 132 332 235 200 188 212 176

injected 3 332 501 215 687 1 742 1 464 1 486 1 485 1 367 1 492 2 945

consumed 13 441 14 095 14 666 15 115 14 730 15 361 15 517 12 997 11 487 9 830 9 155

chemicals from oTher

producTion locaTions

discharged 9 913 1 259 1 533 1 140 917 697 847 753 753 692 952

injected 153 228 59 41 210 24 117 114 150

consumed 64 338 419 438 434 614 475 536 0 0

chemicals added

To The exporT flow

discharged 9 113 282 188 311 439 1 664 1 847 1 483 1 951

injected 0 0 0 0 0

consumed 14 616 7 032 4 941 7 805 5 866 5 180 5 443 5 085 5 094 4 665 5 269

producTion chemicals

discharged 8 582 11 343 11 722 11 131 14 049 15 317 17 208 17 033 16 001 17 272 19 577

injected 1 579 4 051 3 706 2 995 5 881 3 323 4 046 4 500 4 403 4 598 4 082

consumed 22 013 32 206 26 865 24 405 30 069 29 131 31 278 27 720 26 816 28 564 29 018

reservoir managemenT

discharged 1 3 1 1 2 0 9 5 2 3

injected 0 0 0 0 0 0

consumed 1 3 1 1 1 2 14 12 14 6 4

pipeline chemicals

discharged 1 259 1 746 389 962 1 049 2 015 516 917 1 308 3 245 4 130

injected 17 20 0 146 599 936 494

consumed 1 265 1 898 663 2 159 4 886 5 189 3 385 2 973 2 477 4 609 7 029

ToTal

total discharged 176 398 129 996 101 944 90 441 104 260 121 597 127 240 174 228 139 009 150 332 160 162

total injected 94 890 86 318 90 360 85 385 89 165 84 000 96 560 73 973 52 515 46 829 48 621

total consumed 603 767 407 643 388 919 387 897 400 267 432 904 443 381 480 640 481 756 434 472 453 747

19

56

TAB

LES

klif category descriptionklif colourcategory 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

other chemicals Yellowconsumption 79 178 438 83 914 962 85 297 097 90 591 982 94 904 859 94 500 238 92 409 851 103 061 375 80 140 772 68 288 728

discharge 10 976 671 10 599 282 10 240 472 11 077 604 12 004 946 12 818 860 14 701 037 11 727 338 12 304 885 7 574 427

biodegrability < 20% redconsumption 3 450 264 3 674 490 2 997 005 2 928 386 3 016 508 3 079 264.00 2 144 671 2 386 670 1 493 063 1 287 072

discharge 331 007 210 125 59 872 17 794 13 236 10 515 16 318 14 455 6 403 3 600

biodegrability < 20% and toxicity ec50

or lc50 ≤ 10 mg/lblack

consumption 35 837 115 260 50 683 31 908 4 141 1 405 1 233 20 616 11 994 10 853

discharge 2 257 403 685 2 147 398 459 66 80 108 1 050

biodegrability < 20% and log Pow ≥ 5 blackconsumption 180 826 95 102 69 251 7 464 990 908 1 173 1 238 234 1 128 385 694 302

discharge 2 653 1 486 2 365 861 569 824 1 010 1 275 405 64

hormone-disrupting substances blackconsumption 1 494 19 800 13 758 0 28 4

discharge 199 175 150 206 100 1 027 61 91 54 10

chemicals on Plonor list greenconsumption 237 163 198 226 931 564 228 475 800 227 535 746 251 002 945 252 779 521 289 681 616 286 277 021 273 273 649 282 200 932

discharge 78 976 339 63 581 604 56 369 558 63 423 630 72 584 564 74 569 494 111 268 937 90 611 749 99 503 072 103 431 611

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

blackconsumption 843 812 1 032 594 497 146 58 6 3

discharge 41.3 20.3 3.3 6.6 0.6 140 19.6 0 3

two out of three categories: biodegradability < 60%, log Pow ≥, ec50 or lc50 ≤ 10 mg/l

redconsumption 4 022 934 3 953 650 3 378 432 2 730 168 2 359 348 1 181 523 1 061 115 506 942 348 519 801 011

discharge 292 911 81 489 33 273 21 317 9 500 4 579 15 830 1 584 1 710 3 904

water greenconsumption 83 521 489 70 009 327 67 614 818 76 440 340 87 481 939 91 779 833 95 743 461 88 264 187 78 113 608 85 997 959

discharge 39 411 378 27 462 007 23 735 816 29 716 997 40 574 911 39 833 569 48 300 298 36 637 585 38 515 435 43 188 663

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

Yellowconsumption 7 335 852

discharge 3 708 051

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

Yellowconsumption 4 988 993

discharge 1 767 544

consumpTion and discharge of chemicals by environmenTal properTies (KG)

Tab

le

57

Tab

les

klif category descriptionklif colourcategory 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

other chemicals Yellowconsumption 79 178 438 83 914 962 85 297 097 90 591 982 94 904 859 94 500 238 92 409 851 103 061 375 80 140 772 68 288 728

discharge 10 976 671 10 599 282 10 240 472 11 077 604 12 004 946 12 818 860 14 701 037 11 727 338 12 304 885 7 574 427

biodegrability < 20% redconsumption 3 450 264 3 674 490 2 997 005 2 928 386 3 016 508 3 079 264.00 2 144 671 2 386 670 1 493 063 1 287 072

discharge 331 007 210 125 59 872 17 794 13 236 10 515 16 318 14 455 6 403 3 600

biodegrability < 20% and toxicity ec50

or lc50 ≤ 10 mg/lblack

consumption 35 837 115 260 50 683 31 908 4 141 1 405 1 233 20 616 11 994 10 853

discharge 2 257 403 685 2 147 398 459 66 80 108 1 050

biodegrability < 20% and log Pow ≥ 5 blackconsumption 180 826 95 102 69 251 7 464 990 908 1 173 1 238 234 1 128 385 694 302

discharge 2 653 1 486 2 365 861 569 824 1 010 1 275 405 64

hormone-disrupting substances blackconsumption 1 494 19 800 13 758 0 28 4

discharge 199 175 150 206 100 1 027 61 91 54 10

chemicals on Plonor list greenconsumption 237 163 198 226 931 564 228 475 800 227 535 746 251 002 945 252 779 521 289 681 616 286 277 021 273 273 649 282 200 932

discharge 78 976 339 63 581 604 56 369 558 63 423 630 72 584 564 74 569 494 111 268 937 90 611 749 99 503 072 103 431 611

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

blackconsumption 843 812 1 032 594 497 146 58 6 3

discharge 41.3 20.3 3.3 6.6 0.6 140 19.6 0 3

two out of three categories: biodegradability < 60%, log Pow ≥, ec50 or lc50 ≤ 10 mg/l

redconsumption 4 022 934 3 953 650 3 378 432 2 730 168 2 359 348 1 181 523 1 061 115 506 942 348 519 801 011

discharge 292 911 81 489 33 273 21 317 9 500 4 579 15 830 1 584 1 710 3 904

water greenconsumption 83 521 489 70 009 327 67 614 818 76 440 340 87 481 939 91 779 833 95 743 461 88 264 187 78 113 608 85 997 959

discharge 39 411 378 27 462 007 23 735 816 29 716 997 40 574 911 39 833 569 48 300 298 36 637 585 38 515 435 43 188 663

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

Yellowconsumption 7 335 852

discharge 3 708 051

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

Yellowconsumption 4 988 993

discharge 1 767 544

21 22

20

58

TAB

LES

reporting year discharge

1997 21.7

1998 46.4

1999 18.5

2000 33.9

2001 9.9

2002 13.1

2003 9.1

2004 3.7

2005 3.2

2006 4.9

2007 5.0

2008 4.2

2009 7.5

2010 5.6

2011 4.1

2012 5.0

reporting year discharge

1997 20.4

1998 13.2

1999 10.5

2000 11.3

2001 3.29

2002 1.01

2003 0.36

2004 0.16

2005 0.09

2006 0.01

2007 1.58

2008 0.01

2009 1.53

2010 0.06

2011 0.07

2012 1.03

substance 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

other 3.24 0.139 0.228 0.14

arsenic 0.104 0.013 0.144 0.057 0.073 0.067 0.178 0.200 0.149 0.176 0.512

lead 4.18 1.94 1.1 1.63 2.29 2.35 1.39 2.56 1.47 1.48 3.51

cadmium 0.056 0.012 0.011 0.006 0.010 0.009 0.011 0.020 0.012 0.014 0.063

copper 3.23 3.09 1.76 1.08 1.78 2.02 2.1 3.94 3.13 1.67

chrome 0.694 0.809 0.58 0.458 0.482 0.565 0.512 0.821 0.728 0.775 0.88

Mercury 0.021 0.008 0.006 0.004 0.005 0.004 0.003 0.008 0.004 0.008 0.011

discharge of conTaminanTs in chemicalsTOTAl VOlUME (TONNES)

discharge of chemical addiTivesTOTAl VOlUME (TONNES)

discharge of conTaminanTs in chemicals(TONNES)

Tab

le

Tab

le

Tab

le

23

59

Tab

les

Type of discharge 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

chemicals

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

oil

number > 1 cu.m 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

Volume > 1 cu.m 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

Tab

le

acuTe discharges To The sea

24

60

TAB

LES

reportingyear

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

Tab

le

emissions To The air (TONNES)

25

61

Tab

les

source 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

oTher sources

emissions nmVoc 6.39 11.70 211 809 685 1 363 1 137 49

emissions ch4 24.20 92 581 537 1 635 2 559 185

emissions sox 0.14 6.56 0 0 0

emissions nox 73.20 164.00 151 63 15 0

emissions co2 65 491 7 498 2 471 76 603 106 978 91 028 113 691 100 019 62 058

well TesTing

emissions nmVoc 45.30 23.70 8.74 13.70 29.50 9 23 20 85 30 25

emissions ch4 7.43 0.97 0.81 2.94 4.48 2 1 3 8 3 9

emissions sox 33.20 16.60 5.97 4.58 14.20 1 11 12 47 60 13

emissions nox 420 76 51 162 256 117 78 160 470 168 146

emissions co2 114 015 31 658 15 557 40 519 68 001 30 990 32 778 46 011 152 940 55 619 59 745

flaring

emissions nmVoc 143.00 26.10 25.60 25.90 24.40 2 074 236 92 73 76 75

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

boilers

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

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 890 881 922 919 888 905 898 883 890 867 883

emissions ch4 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

Tab

le

emissions To The air by source (TONNES)

26

27

62

TAB

LES

reporting year nmvoc emissions ch4 emissions

1997 5 514 9 728

1998 4 998 10 471

1999 3 933 7 489

2000 4 930 10 339

2001 5 272 12 195

2002 5 435 12 809

2003 7 208 13 804

2004 7 555 14 456

reporting year nmvoc emissions ch4 emissions

2005 7 411 14 410

2006 6 617 14 057

2007 7 701 14 935

2008 9 114 19 023

2009 9 161 18 483

2010 7 186 18 068

2011 8 254 19 181

2012 10 083 18 267

Type 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

sTorage

emissions nmVoc 24 607 11 683 9 971 6 163 4 251 2 099 3 578 6 397 4 607 4 041 2 978

emissions ch4 1 307 496 1 024 465 580 119 332 998 308 596 337

loading

emissions nmVoc 189 991 151 696 122 137 78 000 66 677 61 954 34 714 27 032 21 483 15 072 17 409

emissions ch4 15 639 13 754 13 572 10 650 7 940 7 521 6 631 5 890 4 017 2 711 2 894

Tab

leTa

ble

emissions of ch4 and nmvoc from diffuse sources and cold venTing (TONNES)

emissions of ch4 and nmvoc from sTorage and loading (TONNES)

28

29

63

Tab

les

reporting year combusted diesel (tonnes)

combusted gas (cu.m)

combusted oil (tonnes)

1997 0 11 707 758 29 697

1998 325 19 296 566 22 527

1999 1 336 12 086 301 16 498

2000 34 844 7 186 823 12 076

2001 325 26 310 306 32 142

2002 366 30 950 368 12 792

2003 9 3 639 428 7 128

2004 1 164 3 363 520 1 461

reporting year combusted diesel (tonnes)

combusted gas (cu.m)

combusted oil (tonnes)

2005 103 12 245 846 3 840

2006 43 18 662 837 8 558

2007 0 8 304 214 2 469

2008 0 4 442 709 6 997

2009 15 11 509 318 6 301

2010 48 31 426 218 24 947

2011 88 6 046 803 7 483

2012 0 8 560 987 10 891

other blastingsand

eewaste glass

food contami-

natedmetal paper

cardboard (brownpaper)

plastic residualwaste wood

wet organic

waste

1997 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

Tab

leTa

ble

emissions from well TesTing

separaTed wasTe by source(TONNES)

30

64

TAB

LES

water type 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

drilling waste and other 24 501 32 649 19 722 54 624 45 062 32 674 70 664 101 939 94 679 103 894 119 576 142 142 151 704 258 482 308 456 305 669

batteries 83.6 79.7 27.7 62.1 59.1 73.3 77.0 95.7 119.0 118.0 149.0 40.7 32.8 35.6 50.3 32.2

blasting sand 12.1 22.2 182.0 47.4 95.1 130.0 52.1 73.4 61.0 29.4 41.4 72.5 248.0

Mixed chemicals w/halogen 72 929 8 432 20 174 33 326 6 661 1 354 12 081 7 593 5 341 118 381 916 5 084 6 978

Mixed chemicals w/metal 3.2 0.6 4.4 12.3 4.4 10.1 4.4 9.2 6.4 37.4 0.7 0.3 0.2 0.3 0.2

Mixed chemicals wo/halogen or heavy metals 95.4 392 303 93.2 820 111 139 163 387 137 170 69 54 28 30 119

lightbulbs 14.9 21.3 25.1 29.4 37.6 38.4 36.9 25.3 37.3 27.7 33.8 8.5 6.0 4.1 5.6 8.5

Paint 133 121 76 205 230 362 350 282 451 433 289 139 67 164 83 159

oil-contaminated waste 2 304 2 894 1 944 1 882 2 192 2 967 1 673 1 815 3 098 3 220 3 876 1 256 1 218 1 088 1 966 1 291

Pure chemicals w/halogen 0.3 59.4 1.1 1.9 0.8 0.6 3.8 1.4 442 11 43 6 0 0 0

Pure chemicals w/heavy metals 0.7 1.1 0.6 0.9 3.2 1.3 12.1 15.5 28.6 16.4 10.8 12.2 4.7 2.8 7.6

Pure chemicals wo/halogen or heavy metals 83.3 36.8 180 211 101 94.8 87 240 102 123 35 34 6 17 7

spray cans 26.7 4.4 7.8 9.4 11.4 10.6 5.5 11.9 14.9 18.8 23.1 2.5 3.6 3.3 5.2 2.3

Tab

le

hazardous wasTe (TONNES)

65

Tab

les

water type 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012

drilling waste and other 24 501 32 649 19 722 54 624 45 062 32 674 70 664 101 939 94 679 103 894 119 576 142 142 151 704 258 482 308 456 305 669

batteries 83.6 79.7 27.7 62.1 59.1 73.3 77.0 95.7 119.0 118.0 149.0 40.7 32.8 35.6 50.3 32.2

blasting sand 12.1 22.2 182.0 47.4 95.1 130.0 52.1 73.4 61.0 29.4 41.4 72.5 248.0

Mixed chemicals w/halogen 72 929 8 432 20 174 33 326 6 661 1 354 12 081 7 593 5 341 118 381 916 5 084 6 978

Mixed chemicals w/metal 3.2 0.6 4.4 12.3 4.4 10.1 4.4 9.2 6.4 37.4 0.7 0.3 0.2 0.3 0.2

Mixed chemicals wo/halogen or heavy metals 95.4 392 303 93.2 820 111 139 163 387 137 170 69 54 28 30 119

lightbulbs 14.9 21.3 25.1 29.4 37.6 38.4 36.9 25.3 37.3 27.7 33.8 8.5 6.0 4.1 5.6 8.5

Paint 133 121 76 205 230 362 350 282 451 433 289 139 67 164 83 159

oil-contaminated waste 2 304 2 894 1 944 1 882 2 192 2 967 1 673 1 815 3 098 3 220 3 876 1 256 1 218 1 088 1 966 1 291

Pure chemicals w/halogen 0.3 59.4 1.1 1.9 0.8 0.6 3.8 1.4 442 11 43 6 0 0 0

Pure chemicals w/heavy metals 0.7 1.1 0.6 0.9 3.2 1.3 12.1 15.5 28.6 16.4 10.8 12.2 4.7 2.8 7.6

Pure chemicals wo/halogen or heavy metals 83.3 36.8 180 211 101 94.8 87 240 102 123 35 34 6 17 7

spray cans 26.7 4.4 7.8 9.4 11.4 10.6 5.5 11.9 14.9 18.8 23.1 2.5 3.6 3.3 5.2 2.3

66

9 Terms and abbreviaTions

CH4 MethaneCO2 Carbon dioxidenmVOC non-methane volatile organic compoundsNOx nitrogen oxidesSOx sulphur oxidesSO2 sulphur dioxide

b/d barrels per dayoe oil equivalentscm 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.

OsparOslo-Paris convention for the protection of the marine environ-ment of the north-east Atlantic. Fifteen countries with coasts on or rivers emptying into these waters are signatories.

Plonor “Pose little or no risk to the marine environment”, a list from Ospar of chemical compounds considered to have little or no impact on the marine environ-ment 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 oeOil 1 barrel = 0.159 scmCondensate 1 tonne = 1.3 scm oeGas 1 000 scm = 1 scm oeNGL 1 tonne = 1.9 scm oe

norsk olje og gass

Sentralbord: 51 84 65 00E-post: fi rmapost@norog.no

forus (hovedkonTor)

PostadressePostboks 80654068 Stavanger

besøksadresseVassbotnen 14313 Sandnes

oslo

PostadressePostboks 5481 Majorstuen0305 Oslo

besøksadresseNæringslivets HusMiddelthunsgate 27Majorstuen

TromsØ

besøksadressebankgata 9/119008 Tromsø

PostadressePostboks 4489255 Tromsø

© Norsk olje og gass 05-2013.

Design:

Foto:

Norsk olje og gass (forside og side 4)

Tom Haga (side 6, 43 og 44)

Harald Pettersen / Statoil (side 8, 29, 34, 39 og 40)

Getty Images (side 11 og 15)

Kim Laland / Statoil (side 12)

Anne Lise Norheim (side 18)

Marit Hommedal / Statoil (side 20)

Tanaka Juuyoh (side 22)

Thomas Brekke / Norsk olje og gass (side 26)

Kjetil Alsvik / Statoil (side 31)

Ole Jørgen Bratland / Statoil (side 33)

Øyvind Hagen / Statoil (side 38)

Papir: Multidesign (240/130g)

Opplag: 800 (Norsk) / 300 (Engelsk)

Trykkeri: HBO AS

norwegian oil and gas associaTion

Switchboard: +47 51 84 65 00E-mail: fi rmapost@norog.no

forus (head office)

Mail addressP O box 8065NO-4068 Stavanger

Visiting addressVassbotnen 1NO-4313 Sandnes

oslo

Mail addressP O box 5481 MajorstuenNO-0305 Oslo

Visiting addressNæringslivets HusMiddelthunsgate 27Majorstuen

TromsØ

Mail addressP O box 448NO-9255 Tromsø

Visiting addressbankgata 9/11NO-9008 Tromsø

© Norwegian Oil and Gas Association 05-2013.

English translation: Rolf E Gooderham

Design:

Photos:

Norwegian Oil and Gas (front cover and page 4)

Tom Haga (pages 6, 43 and 44)

Harald Pettersen / Statoil (pages 8, 29, 34, 39 and 40)

Getty Images (pages 11 and 15)

Kim Laland / Statoil (page 12)

Anne Lise Norheim (page 18)

Marit Hommedal / Statoil (page 20)

Tanaka Juuyoh (page 22)

Thomas Brekke /Norwegian Oil and Gas (page 26)

Kjetil Alsvik / Statoil (page 31)

Ole Jørgen Bratland / Statoil (page 33)

Øyvind Hagen / Statoil (page 38)

Paper: Multidesign (240/130g)

Print run: 800 (Norwegian) / 300 (English)

Printer: HBO AS

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