Although not a new concept, carbon taxes have become a hot topic around the globe, ever-growing in the last decade. Canada is no different. At home, Canadians are paying carbon taxes on several different services, from fueling vehicles to heating our homes. The same can be said for industrial emitters. They pay carbon tax based on historical emission rates as well as emission reduction targets set by government legislation.
Why? According to the Government of Canada:
A price on carbon pollution is an essential part of Canada’s plan to fight climate change and grow the economy. It is one of the most efficient ways to reduce greenhouse gas emissions and stimulate investments in clean innovation. It creates incentives for individuals, households, and businesses to choose cleaner options.
Alberta has implemented carbon taxes for large emitters since 2007 and many in situ projects are part of the program. In situ projects combust natural gas to generate steam, which is then injected into the underground reservoir to heat and mobilize bitumen. During the natural gas combustion process, carbon dioxide and other greenhouse gases are generated and released into the atmosphere. These emissions are measured and a carbon tax is applied to them.
Over the last 4 years, there have been many changes and updates to legislation at the federal and provincial level. Canada is looking to achieve emissions neutrality by 2050 and a price on carbon is part of our government’s solution to this complicated problem. In this blog, we will discuss the impact of carbon price legislation on in situ projects.
Summary:
Example Calculation
Note: Yellow is a user input, green is a designated value used for calculation and blue is a calculated value.
Carbon price has the biggest impact on carbon tax. The federal government plans to increase the carbon tax to $170/tonne by 2030. In the immediate future (2022), the carbon tax will sit at $50/tonne. The Alberta TIER program is currently following the federal carbon pricing model.
The industry has been reducing operating costs since the 2014 oil price crash and many in situ operators have achieved operating costs below $12/bbl of bitumen. With a carbon price of $50/tonne CO2 by 2022, a project with SOR of 2.5 would pay $0.60/bbl of bitumen production in 2030 but it would be $2/bbl of bitumen production with $170/tonne CO2. This is a 17% increase to $12/bbl of operating costs. A SOR of 2.5 is relatively low in the industry; projects with a higher SOR will see further increase in carbon tax.
The following graph shows the impact of carbon pricing and project SOR on carbon tax. The following graph assumes constant project SOR throughout the life of a project:
With a SOR of 4 and $170/tonne CO2 carbon tax, a project that is starting in 2021 will pay carbon taxes of approximately $5/bbl of bitumen by 2040. The additional $5/bbl of bitumen operating cost would impact in situ project economically but it is relatively minor when compared to the swing in oil prices over the last 5 years. For in situ projects, oil price is the biggest driver in project economics due to large upfront facility capital investment and longer payout periods. If a project has announced that it is now uneconomic due to $170/tonne CO2 carbon tax, that project was likely already marginal, even without carbon tax, since a $5/bbl decrease in oil price is not uncommon.
The introduction of higher carbon tax is not the main reason why Alberta has not seen any new in situ projects being built. But it does introduce uncertainties to the industry with the constant influx of legislation and changing carbon price. GLJ continues to monitor federal and provincial legislation for updates, and is running a series of carbon tax sensitivities to better understand the impact of a higher, future carbon tax on project economics.
Angie has over twelve years of experience in the oil and gas industry and joined GLJ in 2014. She has a strong foundation in development, operation and evaluation of thermal in situ projects across Western Canada. She has also evaluated various EOR projects, conventional and unconventional assets. More recently her focus has been on changes in Canada Greenhouse Gas legislation and the impact on project economics.