At this time last year, we saw a natural gas market emerge from the winter demand season in a volatile state.
Despite record production, an extended cold front throughout March and April 2018 across the major demand centers of the U. S. caused a historically late beginning to the spring replenishment season. The first injection into storage took place in the third week of April.
With the withdrawal season ending so late, concern grew about the gap of natural gas storage levels compared to the five-year average. There was a 30% difference between storage levels at the end of winter 2018 and the five-year average at the time. However, strong injections throughout June lowered the deficit to 19.5% by early summer.
These circumstances gave way to the state of the natural gas market we are seeing in 2019. While natural gas injections remained strong leading up to the winter 2019 withdrawal season, storage levels were at a deficit of 20% to the five-year average at the beginning of winter, and weather forecasts predicted that we would see another cold winter much like that of 2018.
Weather, as it turns out, is perhaps the most defining factor of the natural gas market, especially as it relates to 2019. In this article, we will examine the supply-and-demand factors that affect the natural gas market of today and analyze how current events are likely to affect power prices going forward.
The general supply-side factors affecting natural gas prices are typically identified as production, imports and storage levels. Storage levels could be seen as a product of supply, not a factor influencing it. We must bear in mind that the market is reactive more often than it is proactive, so prices typically shift in response to the Energy Information Agency’s (EIA) weekly storage report.
We entered the winter of 2019 with storage levels in deficit of 30% to the five-year average, a typically bullish sign for the natural gas market, especially with predictions of a cold winter. Early winter forecasts proved misguided, however, because (despite a few polar-vortex-related weather events) January 2019 was marked as the third-warmest on record since these highs and lows started being tracked 140 years ago. There were some cold fronts in December, which kept natural gas storage levels at 20% lower than the five-year average, but these deficits shifted to 11% during the warm January.
Despite low storage levels, which typically increase natural gas prices, production continued to serve as a hard cap on frequent or sustained price growth for the natural gas market. The U.S. experienced volatile spikes during the polar-vortex-related weather event. However, natural gas prices throughout the early winter of 2019 were typically below the $3/MMBtu mark – a psychological point for the industry.
This is in large part due to continually high production bolstering and helping to cushion sudden and dramatic increases to demand. Natural gas production has trended increasingly high due in large part to more efficient drilling operations and increased oil prices present during late 2018 and early 2019. Natural gas production as a byproduct of oil drilling is a huge factor when it comes to the production of natural gas, even as natural-gas-specific rig counts may flatten or decline.
Despite our abundance of natural gas production, we rely on Canadian natural gas imports to supply parts of the country that are not serviced by pipeline networks and do not have the capacity to utilize U.S.-produced gas for power generation and heating demand. Canadian gas is imported primarily to satisfy the needs of the western and midwestern U.S., so prices in these areas are typically affected by domestic Canadian demand as well as their own heating needs.
Natural gas imports into the U.S. have been declining since 2007 due in large part to ramping U.S. natural gas production. The U.S. became a net exporter for natural gas in 2017.
The demand factors for natural gas can be summarized as weather, economic growth, exports and the availability and prices of competing fuels. The first of these factors is perhaps the most defining thus far in 2019. Weather is never fully predictable, simply because of nature’s volatility and environmental factors that render well-informed and reasonable analysis fallible.
As mentioned, the winter weather of 2018 set the stage for the 2019 season. Cold fronts through April 2018 caused a late start to the injection season. Despite promising injections through the following summer, we entered winter of 2019 at a storage deficit. Predictions were, at the time, that winter would prove long and cold, but these predictions weren’t quite accurate. January 2019 was the third warmest on record.
Interestingly, the reverse also proved true. When winter forecasts projected a warm February, the U.S. was hit with a polar-vortex-related weather event that caused immense heating-related energy demand and spiked prices temporarily in some communities.
Going forward, we should continue to expect anomalous and unpredictable weather to be a factor in our estimates of energy. Historical data shows that weather anomalies are increasing in frequency throughout the latter half of this decade, and we have not yet seen indication that temperatures will begin to follow a pattern of historic norms again in the years to come.
Economic growth is a major factor in the natural gas market for a simple reason: businesses need power. My research has shown some interesting differences of opinion over the trends for manufacturing growth in the U.S., but factually speaking, manufacturing in the U.S. is growing faster than overall GDP, which is a sign that we are seeing some increases in the industry domestically.
One particular sector that is expected to generate increased natural gas demand is methanol plants. Methanol plants are among the most natural-gas-intensive industrial users because they require the gas both as a feedstock and to process heat.
EIA reports that three new plants are expected to come online this year and in 2020, which will add significantly to the consumption of natural gas domestically. One plant, expected to be the largest in the country, is estimated to consume 0.15 billion cubic feet per day.
Substantial growth has been seen in the field of liquefied natural gas (LNG) exports. In addition to our growing exports to Mexico, the U.S. has found an attractive market in the transport of LNG from export terminals to countries across the ocean.
In late February, Federal Energy Regulatory Commission worked through a gridlock to approve a new LNG export terminal for the first time in two years. This new export terminal is a major step toward EIA’s projection that the U.S. will launch an additional three export terminals and more than double its current LNG export capacity to 8.9 Bcf/day by the end of this year.
As LNG export capacity increases, there will be more incentive for companies to transport their LNG to places such as Asia and Europe that wish to transition away from less efficient and more polluting coal-fired power plants to natural gas. By the same token, that means that the supply of domestic natural gas shall decrease, which is a bullish factor for natural gas prices.
As we mentioned, natural gas production began in earnest in the U.S. during 2007. Not coincidentally, coal consumption peaked that same year and has been on a decline ever since.
April 2015 was the first year that more electricity was generated from natural gas than from coal on a monthly basis, with 2016 being the first year-over-year annual basis. 2017 and 2018 have continued that trend, and in the U.S. today it is apparent that natural gas will continue to increase as coal consumption declines. The primary reason for this is the cost of coal comparatively to natural gas. Natural gas prices have remained relatively low since the growth of gas in 2007, and this sustained low price has kept the cost of generating electricity with the resource more competitive than that of coal.
Environmental concerns have also played a large factor in the growth of natural gas demand as compared to coal. The 2015 requirement of the Mercury and Air Toxics Standards represented a peak in coal-fired electric generator retirements. This was partially due to age but also due to an inability of the plants to meet the standards.
Retirements have continued throughout the years since. 2018 saw many coal plants retire. Natural gas, on the other hand, has far fewer emissions than coal, which has helped sustain its growth.
Moving into 2019, it will be interesting to see what comes of renewables and their relationship to natural-gas-related demand. Congress has signaled some interest in pursuing a push toward more renewable-energy sources, but we will have to see if and how that manifests before determining its exact impact as related to natural gas as a market.
As we look toward the future, we should likely expect weather-related volatility, environmental impact and economic factors to play a major role in both natural gas and the energy market as a whole. These factors have begun to make their way into the national discourse, which is often an indication of the market’s trend. What exactly comes of the national discourse is unknown, but it will be interesting to monitor how the market reacts to the modern landscape.
For more information and insight into energy market trends, contact APPI Energy 112 E. Market Street, Salisbury, MD 21801; tel: 800-520-6685; web: www.appienergy.com. For 23 years, APPI Energy has delivered comparisons of supplier prices and contracts and negotiates supply solutions that reduce and manage energy costs on an ongoing basis for commercial and industrial customers.