Oil and Gas

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• Production
• Trade and Transportation

Production

Crude Oil

• Since 2018, Nova Scotia has not produced any crude oil or crude oil equivalents (Figure 3).
• Between 2000 and 2018, Nova Scotia produced condensate/pentanes plus at the ExxonMobil-operated Point Tupper Fractionator Plant. In 2018, ExxonMobil applied to the province to abandon its fractionator as part of the abandonment of its natural gas producing Sable Offshore Energy Project. Production at Point Tupper ceased by May 2018.
• There are currently no active exploration licenses or projects in the offshore of Nova Scotia.

Refined Petroleum Products (RPPs)

• Nova Scotia does not have any refineries. Imperial Oil’s Dartmouth refinery closed in 2013. The facility now operates as an oil products terminal.
• In April 2022, NuStar Energy L.P. sold its 7.8 million-barrel storage terminal in Point Tupper to EverWind Fuels. The terminal is one of the largest RPP storage and blending facilities in Atlantic Canada. It serves markets in Atlantic Canada and the United States (U.S.) East Coast. EverWind plans to turn the terminal into Atlantic Canada’s first green ammonia production facility in 2026.^Footnote 6

Natural Gas/Natural Gas Liquids (NGLs)

• Nova Scotia has not produced any natural gas since 2018. (Figure 3)
• Natural gas in Nova Scotia was previously produced offshore at ExxonMobil’s Sable Offshore Energy Project and Ovintiv’s Deep Panuke project until 2018 (Encana changed its name to Ovintiv in 2020).
• The Sable Offshore Energy Project, Canada’s first offshore natural gas project, was commissioned in 1999 and ceased production on 31 December 2018. The plugging and abandonment of all wells was completed in 2019. A post-abandonment monitoring program was conducted in 2021 and the project was officially closed.
• Deep Panuke was commissioned in 2013 and ceased production in May 2018. The plugging and abandonment of Deep Panuke’s five wells was completed in August 2020. A post-abandonment monitoring program was completed in 2021 and the project was officially closed.^Footnote 7
• Nova Scotia currently produces no NGLs. Previously, NGLs were produced from natural gas from the Sable Offshore Energy Project, which were then processed at the Goldboro gas plant. NGLs from Goldboro were then shipped by pipeline to the Point Tupper plant for fractionation into propane, butane, and pentanes plus. The gas plant, pipeline, and fractionation plant were shut down when Sable Offshore Energy Project permanently ceased production. Infrastructure associated with gas production, including the gas plant, pipeline, and fractionation plant, has been shut down.
• Since 2012, a prohibition on high-volume hydraulic fracturing for onshore gas development in shale formations has been in place in Nova Scotia.
• Nova Scotia’s offshore exploration and production is regulated by the Canada-Nova Scotia Offshore Petroleum Board (CNSOPB). In April 2022, the Government of Canada and the Province of Nova Scotia announced the intent that the CNSOPB will expand its mandate to include the regulation of offshore renewable energy development, and that it would be renamed to the Canada-Nova Scotia Offshore Energy Board (CNSOEB) to reflect its new mandate.^Footnote 8

Hydrogen

• In 2022, EverWind Fuels proposed converting the former NuStar Energy RPP storage and blending terminal in Point Tupper into a green hydrogen and green ammonia production hub.^Footnote 9 The project received approval from Nova Scotia’s Minister of Environment and Climate Change in February 2023. The project’s first phase, producing 240,000 tonnes of green ammonia per year, is expected to be online in 2026.^Footnote 10
• In April 2023, Nova Scotia’s Minister of Environment and Climate Change approved Bear Head Energy’s green hydrogen and green ammonia production plant in Point Tupper. The plant will have the capacity to produce up to 350,000 tonnes of hydrogen each year, which it will then convert into two million tonnes of ammonia each year before shipping to customers overseas. Initial engineering design work is currently underway, with first production expected by 2028.
• In December 2023, Nova Scotia released its Green Hydrogen Action Plan.

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Trade and Transportation

Crude Oil and Liquids

• There are no crude oil pipelines or crude-by-rail facilities in Nova Scotia.
• Since Nova Scotia is not connected to oil pipeline systems and it does not have any refineries, it must import RPPs. RPPs are imported from the Irving Refinery in New Brunswick, as well as other countries including the U.S., the Netherlands, and Belgium.

Natural Gas

• Nova Scotia relies entirely on imported natural gas, which arrives via the Maritimes and Northeast Pipeline (M&NP) (Figure 5). The M&NP connects to pipelines in the northeast U.S., which are connected to the broader, North American market, including western Canada. The Canadian portion of the M&NP starts at St. Stephen, New Brunswick, and ends near Halifax and Goldboro in Nova Scotia. In 2023, the M&NP shipped 189 MMcf/d of gas into Nova Scotia and New Brunswick. Some Nova Scotia companies ship gas all the way from western Canada to Nova Scotia through multiple transmission pipelines.
• Nova Scotia also receives some gas supply in the form of liquefied natural gas (LNG), which is imported into Canada from global sources to the Saint John LNG import terminal in New Brunswick. Imported LNG is transported through New Brunswick on the Emera Brunswick Pipeline to a connection with the M&NP. Once on the M&NP, the gas can flow north to delivery points in New Brunswick and Nova Scotia or south to delivery points in the northeast U.S.
• The M&NP was originally built to transport natural gas from offshore Nova Scotia to markets in the U.S. northeast, but no longer exports gas to any significant degree. Until 2017, exports on the M&NP exceeded imports, but with the decline (and end) of Nova Scotia’s offshore production, the M&NP is a net-importing pipeline. In 2023, only 0.02 MMcf/d was exported.
• Nova Scotia does not have any underground natural gas storage facilities, so it must rely on pipeline imports to meet natural gas demand. Alton Natural Gas Storage LP, a subsidiary of AltaGas, had received environmental approval from the province in 2013 to develop a natural gas underground storage facility near Alton. In October 2021, AltaGas decided not to continue with development of the project. Decommissioning work began in 2023.^Footnote 11

Liquefied Natural Gas (LNG)

• In November 2023, Pieridae Energy announced that it would abandon plans to build the Goldboro LNG export project in Nova Scotia and sell the Goldboro assets.^Footnote 12 The sale was finalized in July 2024.^Footnote 13 The $3 billion facility was proposed in 2012 to export 320 MMcf/d of natural gas to European markets. Pieridae Energy had previously received authorization from the Nova Scotia Utilities and Review Board (NSUARB) to construct Goldboro LNG export facility and an export and import licence from the NEB (now CER).^Footnote 14
• Bear Head LNG Project was initially proposed in 2001 as an LNG terminal in the Strait of Canso.^Footnote 15 The project received authorization from the NSUARB to construct the facility and an export and import licence from the NEB.^Footnote 16 In 2021, Bear Head began to transition the project from LNG to low-carbon hydrogen and ammonia.

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Energy Use

Total Energy Consumption

• End-use demand in Nova Scotia was 156 petajoules (PJ) in 2020. The transportation sector was responsible for 39% of total demand, followed by residential at 28%, industrial at 18%, and commercial at 15% (Figure 6). Nova Scotia’s total energy demand was the eighth largest in Canada, and the eleventh largest on a per capita basis.
• RPPs, including gasoline, diesel, and heating oil, were the most consumed fuel in Nova Scotia, accounting for 92 PJ, or 59% of total end-use demand. Electricity and biofuels accounted for 37 PJ (23%) and 17 PJ (11%), respectively (Figure 7).

Refined Petroleum Products (RPPs)

• Nova Scotia’s motor gasoline demand in 2022 was 1,211 litres per capita, 17% above the national average of 1,035 litres per capita.
• Nova Scotia’s diesel demand in 2022 was 618 litres per capita, 20% below the national average of 772 litres per capita.
• RPP prices in Nova Scotia have been regulated by the NSUARB since 2009. The NSUARB sets wholesale prices, minimum and maximum retail mark-ups, and maximum retail prices for gasoline and diesel.^Footnote 17

Natural Gas

• In 2023, Nova Scotia consumed an average of 77.2 MMcf/d of natural gas, which was less than 1% of total Canadian demand.
• Nova Scotia’s industrial sector consumed 57.7 MMcf/d of natural gas in 2023. The commercial and residential sectors consumed 18.7 MMcf/d and 0.7 MMcf/d, respectively.

Electricity

• In 2020, annual electricity consumption per capita in Nova Scotia was 10.4 megawatt-hours (MWh). Nova Scotia ranked ninth in Canada for per capita electricity consumption and consumed 29% less than the national average.
• Nova Scotia’s largest consuming sector for electricity in 2020 was residential at 4.8 TWh. The commercial and industrial sectors consumed 3.4 TWh and 2.0 TWh, respectively.

GHG Emissions

• Nova Scotia’s GHG emissions in 2022 were 14.8 megatonnes of carbon dioxide equivalent (MT CO₂e).^Footnote 18 Nova Scotia’s emissions have declined 25% since 1990 and 35% since 2005. The Environmental Goals and Climate Change Reduction Act’s targets are to reduce greenhouse gas emissions by at least 53% below 2005 levels by 2030 and achieve net-zero greenhouse gas emissions by 2050.
• Nova Scotia emissions per capita are 14.4 tonnes CO₂e, which is 21% below the Canadian average of 18.2 tonnes per capita.
• The largest emitting sectors in Nova Scotia are electricity generation at 39% of emissions, transportation at 35%, and buildings (residential and commercial) at 14% (Figure 8).
• In 2022, Nova Scotia’s power sector emitted 5.8 MT CO₂e emissions, which represents about 12% of Canadian emissions from power generation.
• The greenhouse gas intensity of Nova Scotia’s electricity grid was 660 grams of CO₂e per kilowatt-hour (g of CO₂e/kWh) electricity generated in 2022. This is a 25% reduction from the province’s 2005 level of 880 g of CO₂e/kWh. The national average in 2022 was 100 g of CO₂e/kWh (Figure 9).