Market Snapshot: Western Canada’s natural gas export pipelines high utilization continued in 2024 and the first half of 2025

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Release date: 2025-11-19

Pipelines that export natural gas produced in the Western Canadian Sedimentary Basin (WCSB) continue to operate at high utilization rates; driven by continued high production levels in the WCSB, and extremely cold temperatures in export markets the previous winter.

Natural gas production from western Canada is mostly transported through three key pipeline systems:

These pipelines either export directly to the United States (U.S.) or interconnect with other pipelines, supplying natural gas to both domestic and export customers. Key delivery points include East Gate^Footnote 1 and West Gate^Footnote 2 on the NGTL system, and the Canada/U.S. border points on Alliance (Elmore) and Westcoast (Huntington) pipelines (see the Pipeline Profiles for precise locations of these key points). Upstream James River is also a major point on the NGTL system—a large portion of natural gas production must pass through this area to reach downstream markets.

Available capacity and seasonal pipeline trends

Natural gas compressor station with frost covering pipes and valves on a cold wintery day. The sun is rising in the background and there are clouds in the sky.

Natural gas pipeline available capacity and throughput generally increase in the winter. In colder temperature, natural gas molecules pack closer together, so more gas fits in the pipe and more can be shipped. Winter weather also drives up demand for natural gas for use in space heating. Seasonal increases in natural gas production in western Canada also occur in the colder months when gas drilling activity increases and stored natural gas is withdrawn, both of which increase supply available for transport.^Footnote 3 At times, throughput can exceed reported available capacity because of changes that occur between the time available capacity was estimated and when shipments occur (due to factors like ambient temperatures, outages, and downstream constraints).

Figure 1: Monthly throughput and available capacity on the NGTL system

Source and Text Alternative

Source: CER – Pipeline Throughput and Capacity Data

Text Alternative: These combined area and line charts illustrate monthly throughput and available capacity on the NGTL natural gas system at East Gate, West Gate, and Upstream James River from January 2019 to June 2025. Available capacity on the NGTL system has been increasing incrementally in the last few years. Additionally, available capacity and utilization increase in the winter. See the NGTL Pipeline Profile for the location of the key points.

Note: At times, throughput can exceed reported available capacity because of changes that occur between the time available capacity was estimated and when shipments occur (due to factors like ambient temperatures, outages, and downstream constraints).

NGTL available capacity continues to increase at West Gate and Upstream James River

Throughput at the Upstream of James River key point increased by 2.7% from 2023 to an average of 11.76 billion cubic feet per day (Bcf/d) in 2024. It continued to increase year-over-year in the first half of 2025, averaging 12.70 Bcf/d in Q1 (+6.2% over Q1 2024) and 11.95 Bcf/d in Q2 (+3.5% over Q2 2024). The average available capacity increased from 13.04 Bcf/d in 2023 to 13.50 Bcf/d in 2024. It further increased to 14.16 Bcf/d in November 2024 and remained at this level through Q1 of 2025, declining slightly to 14.01 Bcf/d in Q2.

Natural gas flows at the West Gate key point increased by 0.9% from 2023 to 2.62 Bcf/d in 2024. Throughputs in the first half of 2025 continued to increase, averaging 2.96 Bcf/d in Q1 2025 (+6.0% from Q1 2024) and 2.58 Bcf/d in Q2 2025 (+8.3% from Q2 2024). The available capacity at West Gate key point was 3.10 Bcf/d throughout most of 2024 and increased slightly to 3.14 Bcf/d in November of 2024 and remained at this level throughout the first half of 2025. Utilization at West Gate in Q1 2025 almost reached full capacity, peaking at 98% in January.

Th roughput at the East Gate key point averaged 4.88 Bcf/d in 2024, which is a significant 11.8% increase from 2023. An even larger increase came in Q1 2025, when throughput was 5.68 Bcf/d, 16.1% higher than Q1 2024. Q2 2025 saw a slightly more modest year-over-year increase with throughput at 4.99 Bcf/d (+7.3% from Q2 2024). The average available capacity at East Gate key point was 5.07 Bcf/d in 2023, and 4.90 Bcf/d in 2024. In November 2024 capacity increased at this point to 5.09 Bcf/d and remained at this level throughout Q1 2025, before decreasing to 4.82 Bcf/d in Q2 2025. East Gate has been almost fully utilized since November 2023, with flows frequently exceeding capacity. In January 2025, throughputs were nearly 14% over available capacity.

In January 2025, extreme cold weather affected much of the U.S. and Canada and increased heating demand in Central and Eastern Canada, and the U.S. Midwest and Northeast, areas fed by the TC Canadian Mainline which connects to NGTL at the East Gate key point. This high winter demand, record production, and the pipelines’ operational ability to utilize cold-weather performance and linepack combined to push throughput above available capacity during winter 2024/2025.available capacity during winter 2024/2025.

Figure 2: Monthly throughput and available capacity on Alliance and Westcoast Pipelines

Source and Text Alternative

Source: CER – Pipeline Throughput and Capacity Data

Text Alternative: These combined area and line charts illustrate natural gas monthly throughput and available capacity on the Alliance Pipeline at the Canada/U.S. border key point near Elmore, Saskatchewan, and the Westcoast Pipeline at the Huntingdon/Fortis BC Lower Mainland key point (which consists of 2 key points at same location: Huntingdon Export and FortisBC Lower Mainland) from January 2019 to June 2025. Westcoast saw a significant increase in winter utilization in the 2024/2025 winter season, while capacity remained the same as the previous three years. In comparison, Alliance seasonal available capacity and utilization have been more stable in the last couple years. See the Alliance and Westcoast Pipeline Profiles for the location of the key points.

Note: At times, throughput can exceed reported available capacity because of changes that occur between the time available capacity was reported and when shipments occur (due to factors like ambient temperatures, unplanned outages, and downstream constraints).

High utilization continues on Alliance Pipeline

The Alliance Pipeline transports liquids-rich natural gas to the Chicago area. Alliance’s throughput at the Canada/U.S. border key point near Elmore, Saskatchewan increased by 1.9% from 2023 to 1.55 Bcf/d in 2024. Q1 and Q2 of 2025 transported 1.68 Bcf/d and 1.55 Bcf/d, respectively, which is approximately 3.0% more than the same quarters the previous year. The Alliance Pipeline has an average annual available capacity of 1.6 Bcf/d. The pipeline has been full since November 2024.

Westcoast Pipeline volumes increase in the winter

The Westcoast Transmission System transports natural gas to consumers in British Columbia (B.C.), other provinces, and the U.S. through interconnecting pipelines. Westcoast’s throughput at the Huntingdon/FortisBC Lower Mainland key point increased by 1.5% from 2023, averaging 1.56 Bcf/d in 2024. Q1 2025 saw record high throughput numbers; 1.88 Bcf/d in Q1 2025, 3.6% higher than Q1 2024. Utilization was the highest in January 2025—7% over capacity. Throughput declined in Q2 2025 to 1.38 Bcf/d, which is equal to Q2 2024. This key point has had an annual average available capacity of 1.71 Bcf/d since 2022 with no recent changes.

Extremely cold temperatures in winter 2024/2025 led to higher heating demand in Vancouver, B.C.’s Lower Mainland, and the U.S. Pacific Northwest. The Westcoast Pipeline is the primary system delivering this heating fuel to these markets. Increased demand, combined with abundant production from the Montney Formation in northeastern B.C., contributed to Westcoast exceeding capacity in the winter season.

Every quarter, major companies are required to report daily pipeline throughput and available capacity data to the Canada Energy Regulator (CER)^Footnote 4. This data is available quarterly on Open Government, Pipeline Profiles, and A look at pipeline flow and capacity.

Footnotes

Footnote 1

At East Gate, the NGTL system connects with two pipelines: TC Canadian Mainline (near Empress, Alberta) and the Foothills Pipeline (near McNeill, Alberta), which supply natural gas to markets in central and eastern Canada, as well as markets in the U.S. Northeast and Mid-west.

Return to footnote 1 referrer

Footnote 2

At West Gate, the NGTL system interconnects with the Foothills Pipeline. Gas travels through the Foothills system to supply communities in south-eastern British Columbia, and for export into western U.S., serving markets in the Pacific Northwest and California.

Return to footnote 2 referrer

Footnote 3

For utilization of major CER-regulated pipelines see: CER – Natural gas – pipeline flow and capacity

Return to footnote 3 referrer

Footnote 4

Pipeline companies regulated by the CER are divided into two groups for financial regulatory purposes. Group 1 consists of those pipeline companies with extensive systems and several third-party shippers. Through the CER’s Filing Manual Guide BB.2 Traffic Data filing requirements, they are required to report capacity and throughput data. Group 2 consists of the remaining pipeline companies that operate smaller, less complex pipelines with few or no third-party shippers. These companies are not subject to the same reporting requirements as Group 1 companies.

Return to footnote 4 referrer

Date modified:: 2025-11-19

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