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Scope 1, Scope 2, and Scope 3 greenhouse gas (GHG) emissions, and the related risks

Shell’s target is to be a net-zero emissions energy business by 2050, in step with society. This means we must therefore report our performance against our operational Scope 1 and 2, and Scope 3 emissions. Scope 1, 2 and 3 emissions are among the metrics we use to mitigate climate risks and seize opportunities in the energy transition, as described in the section “Climate-related metrics and targets”.

Shell’s absolute emissions in 2021

In 2021, our total combined Scope 1 and 2 absolute GHG emissions (from assets and activities under our operational control) were 68 million tonnes on a CO2 equivalent basis, a 4% reduction compared with 2020, and an 18% reduction compared with 2016, the base year. Our Scope 3 emissions from energy products included in our net carbon intensity were 1,299 million tonnes CO2e.

 

Absolute emissions [D], [F] million tonnes of CO2e

Targets [E]

Scope

2016

2019

2020

2021

Target 2030

Target 2050

Scope 1 [A]

72

70

63

60

50% reduction compared with 2016 levels on a net basis

0

Scope 2 [B]

11

10

8

8

0

Scope 3 [C]

1,545

1,551

1,305

1,299

No target

0

[A]

Total direct (Scope 1) GHG emissions from assets and activities under our operational control. It includes emissions from production of energy and non-energy products.

[B]

Total indirect GHG emissions from imported energy (Scope 2) from assets and activities under our operational control using the market-based method. It includes imported energy used for production of energy and non-energy products. We have restated our 2020 emissions from 9 to 8 million tonnes CO2e following a correction of an efficiency factor for steam at one of our assets and a revision to how internal energy transfers of steam and electricity were accounted for at several of our assets to remove double-counting between Scopes 1 and 2.

[C]

Indirect GHG emissions (Scope 3) based on the energy product sales included in Net Carbon Intensity (NCI) using equity boundary. The NCI calculation uses Shell’s energy product sales volume data, as disclosed in the Annual Report and Sustainability Report. This excludes certain contracts held for trading purposes and reported net rather than gross. Business-specific methodologies to net volumes have been applied in oil products and pipeline gas and power. Paper trades that do not result in physical product delivery are excluded. Retail sales volumes from markets where Shell operates under trademark licensing agreements are also excluded from the scope of Shell’s carbon intensity metric.

[D]

Carbon credits are not included in the total emissions.

[E]

Our 2030 and 2050 targets are on the net basis (i.e., including carbon credits). Acquisitions and divestments have been included in the actual performance tracking with the target unchanged. Note that acquisition and divestments could have a material impact on meeting the targets.

[F]

Oil and gas industry guidelines from the International Petroleum Industry Environmental Conservation Association (IPIECA) indicate that several sources of uncertainty can contribute to the overall uncertainty of a corporate emissions inventory. We have estimated the overall uncertainty for our direct GHG emissions (scope 1) to be around 4% and for our energy indirect GHG emissions (scope 2) to be around 6% for 2021 (same for location and market-based methods). IPIECA also note that due to the diversity of scope 3 emissions, sources and the fact that these emissions occur outside the company’s boundaries, the emissions estimates may be less accurate or may have high uncertainty.

The Scope 3 emissions from the energy products we sell account for the majority of our total emissions. When we calculate our emissions, we include emissions not only from the products that we produce ourselves but also from the oil and gas that others produce and resell as products to our customers. Altogether, we sell more than three times more oil and gas products than the oil and gas we extract ourselves. Therefore, to account for Shell’s full effect, we have to include everything we sell in the measurement of our carbon emissions as shown in the charts in the section “Climate-related metrics and targets”.

Scopes 1 & 2 – performance [A]

a Downstreamb Integrated Gas and Renewables and Energy Solutionsc Upstreamd Other Scope 1 & 2 68m tonnes CO 2 e 56% 25% 18% a b c d 1%
[A] Total direct (Scope 1) and energy indirect (Scope 2) GHG emissions from assets and activities under operational control boundary. It includes emissions from production of energy and non-energy products. For Scope 2, we used the market-based method.

Share of energy delivered per energy product type [A]-[F]

0 20 40 60 80 100 2021 2020 2019 nix 2016 Gas (carbon intensity in 2021 was 66 gCO 2 e/MJ) a b Liquefied natural gas (LNG) (carbon intensity in 2021 was 70 gCO 2 e/MJ) c Biofuels (carbon intensity in 2021 was 41 gCO 2 e/MJ) d b a c e d 14% 24% 7% 1% 54% 18% 17% 9% 1% 56% 21% 1% 47% 18% 25% 1% 45% Oil products and gas-to-liquids (GTL) (carbon intensity in 2021 was 91 gCO 2 e/MJ) Power (carbon intensity in 2021 was 66 gCO 2 e/MJ) e 12% 12% 19%
[A] Percentage of delivered energy may not add up to 100% because of rounding.
[B] Total volume of energy products sold by Shell, aggregated on an energy basis, with electricity represented as fossil equivalents. This value is derived from energy product sales figures disclosed by Shell in the Annual Report, Form 20-F and the Sustainability Report.
[C] Lower heating values are used for the energy content of the different products and a fossil-equivalence approach is used to account for electrical energy, so that it is assessed on the same basis as our other energy products.
[D] The NCI calculation uses Shell’s energy product sales volume data, as disclosed in the Annual Report and Sustainability Report. This excludes certain contracts held for trading purposes and reported net rather than gross. Business specific methodologies to net volumes have been applied in oil products and pipeline gas and power. Paper trades that do not result in physical product delivery are excluded. Retail sales volumes from markets where Shell operates under trademark licensing agreements are also excluded from the scope of Shell´s carbon intensity metric.
[E] In 2021, emissions included in carbon intensity of power have been calculated using the market-based method.
[F] The carbon intensity of biofuels provided in the graph “Share of energy delivered per energy product type” reflects the global average for biofuels sold by Shell for 2021.

We undertake external verification of our GHG emissions annually. Our Scope 1 and 2 GHG emissions from assets and activities under our operational control and Scope 3 emissions included in our NCI have been verified to a level of limited assurance.

Drivers of absolute Scope 1 and 2 emissions change in 2021

Scope 1 and Scope 2 GHG emissions changes from 2020 to 2021

million tonnes carbon dioxide equivalent (CO2e)

55 60 65 70 75 2021 2020 2021 2020 55 60 65 70 75 2021 2020 Acquisitions Reduction activities and purchased renewable electricity [C] [D] Emissions [A] [B] a b c Divestments and other reasons Change in output d e 68 (2.2) 2.7 71 (4.0) 0.0
[A] Total Scope 1 and Scope 2 emissions, rounded to the closes million tonnes. Scope 2 emissions were calculated using the market-based method.
[B] We have restated our 2020 emissions from 9 to 8 million tonnes CO2e following a correction of an efficiency factor for steam at one of our assets and a revision to how internal energy transfers of steam and electricity were accounted for at several of our assets to remove double-counting between Scopes 1 and 2.
[C] In addition to reductions from GHG abatement and energy efficiency projects, this category also includes reductions from permanent shutdown of Convent and Tabangao refineries and the impact of transformational activities at our Shell Energy and Chemicals Park in Singapore.
[D] Excludes 1.05 million tonnes of CO2 captured and sequestered by our Quest CCS project in Canada in 2021.

Our direct GHG emissions (Scope 1) (consolidated using the operational control boundary) decreased from 63 million tonnes of carbon dioxide equivalent (CO2e) in 2020 to 60 million tonnes CO2e in 2021, driven by several factors including:

  • the shutdown of the Convent refinery, USA, in late 2020;
  • downtime at the Norco site, USA, due to impacts from Hurricane Ida;
  • divestments in 2020 and 2021 (e.g. the Martinez and Puget Sound refineries in the USA, and the Fredericia refinery in Denmark);
  • sustained emissions reductions (performance against our scorecard and additional reductions as discussed below (page 94); and
  • reductions in methane emissions.

These decreases were partly offset by higher emissions due to the restart of the Prelude FLNG facility in Australia and increased flaring in facilities operated by Shell Nigeria Exploration and Production Company Limited (SNEPCo) in Nigeria.

Total routine hydrocarbons flaring reduced from 0.3 to 0.2 million tonnes of hydrocarbon flared from 2020 to 2021.

Around 60% of flaring in our Upstream and Integrated Gas facilities in 2021 occurred in assets operated by the Shell Petroleum Development Company of Nigeria Limited (SPDC) and SNEPCo. We will continue to work in close collaboration with joint-venture partners and the Federal Government of Nigeria to make progress towards the objective of ending the continuous flaring of associated gas.

Our target to keep methane emissions intensity below 0.2% was met in 2021 with Shell’s overall methane emissions intensity at 0.06% for facilities with marketing gas and 0.01% for facilities without marketing gas. We believe our methane emissions are calculated using the best methods currently available. This target covers all Shell-operated oil and gas assets in our Upstream and Integrated Gas businesses. Methane emissions include those from unintentional leaks, venting and incomplete combustion, for example in flares and turbines.

Our indirect GHG emissions associated with imported energy (Scope 2) (consolidated using the operational control boundary) were 8 million tonnes CO2e in 2021, (using the market-based method), the same as in 2020.

Drivers of absolute Scope 3 emissions change in 2021

Emissions associated with the use of our energy products, Scope 3 emissions, account for the vast majority of our carbon emissions related to energy products. Our total Scope 3 emissions from energy products are largely unchanged from last year. The decrease in 2020 from 2019 mainly relates to a decrease in demand for oil products given market conditions in 2020, and a decrease related to volumes associated with additional contracts being classified as held for trading purposes with effect from January 2020.

Our strategy is based on working with our customers, sector-by-sector, to address the emissions from the use of our products and to help them find ways to reduce their emissions and overall carbon footprint to net zero by 2050.

GHG
greenhouse gas
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SPDC
Shell Petroleum Development Company of Nigeria Limited
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