Any power utility executive will tell you that the industry has been burned by unexpected natural gas price spikes a number of times over the past 10 years.
In some cases, regulators refused to allow the utility to pass on the fuel cost to ratepayers, and investors took the hit in the form of lower earnings.
While this does not happen often, when there is widespread consumer outcry over high electric bills as a result of natural gas price spikes, known in the industry as the “French Revolution effect,” the relationship with regulators can become so contentious as to materially undermine the utility’s earnings profile over a period of years.
That’s why recent moves by various utilities to develop shale gas pipelines, buy production assets, or even lock in long-term, low-priced natural gas with producers should put those firms in a more favorable light among investors. These physical risk-management strategies will keep costs low, protect profit margins, and allow for incremental increases in capital projects.
In fact, federal regulators are encouraging better coordination between electric and natural gas assets. In hearings at the Federal Energy Regulatory Commission in early July, natural gas price spikes during last winter’s polar vortex were blamed on a lack of coordination between natural gas pipelines and electric grid operators.
Though federal regulators are not advocating mergers and acquisitions by any means, many in the industry see a potential second electric-natural gas convergence wave that may lead to mergers between natural gas and power entities.
NextEra Energy Inc’s (NYSE: NEE) subsidiary, Florida Power & Light (FPL), offers one recent example of such a move. In June, the utility announced a partnership with PetroQuest Energy Inc to jointly develop up to 38 gas wells in the Woodford Shale region of Oklahoma.
In the accompanying filing, the company said the wells would provide 30 years of physical gas and save the firm $107 million over the well’s lifetime, since the firm will acquire the gas at the cost of production plus transport charges (as opposed to paying market prices).
In conjunction with its shale project, NextEra has proposed a 330-mile natural gas pipeline that would serve the Mid- and South Atlantic region.
In an interview with Energy Risk magazine, Sam Forrest, vice president of energy marketing and trading at FPL, said a similar long-term hedge with derivatives would be impossible. He explained that while FPL hedges its near- to medium-term exposure to natural gas prices, typically over a 12-month to 24-month period, hedging many years into the future would incur significant capital and credit costs.
Similarly, Dominion Resources Inc (NYSE: DOM) and Duke Energy Corp (NYSE: DUK) announced a partnership in early September to build a 550-mile pipeline that would transport natural gas from the Marcellus and Utica shale regions to fuel new power plants in the utilities’ home states of Virginia and North Carolina, respectively.
These deals as just the beginning of the beginning: As utilities add more natural gas power plants, they will need greater access to natural gas resources to hedge their commodity risk.
Natural Gas Power Generation Will Surpass Coal by 2040