- Nymex July futures down 9.3 cents to $2.454; August down 9.7 cents to $2.460
- Uncertainty caused by tariffs; U.S. “not the only ones that can interfere with the normal flow of business,” says Powerhouse’s Levine
Uncertainty created by U.S. trade policy -- made top-of-mind by President Trump’s announcement of new tariffs on Mexico -- appeared to drive bearish sentiment across multiple energy futures markets Friday, including West Texas Intermediate and heating oil, Powerhouse CEO Alan Levine told NGI.
“We’re starting to develop export markets for natural gas. I think there’s a lot of anxiety now as to what might be available there,” Levine said. “Remember, we’re [the United States is] not the only ones that can interfere with the normal flow of business. So we could easily find...a lot of the markets that we thought might be useful as offtakers” for U.S. supply could close up, at least temporarily.
These concerns on the demand side come as strong production growth has driven large storage injections and put downward pressure on natural gas.
“I don’t think it’s out of the question that we could see natural gas, because of all the production we’re seeing, fall all the way down to” an “ultimate low” at $1.611, the low set back in March 2016, Levine said. “I’m not saying it’s going to happen, but I don’t think we can ignore that possibility.
“...I think this is not a good sign for the bulls. The question becomes, where does the next rally come from? And silence is deafening.”
Bulls may have to pin their hopes on a lift from U.S. forecasts, which as of Friday had not been particularly cooperative in terms of producing June heat.
Provided an opening by an outsized inventory build and a mild forecast, and on a day of broader uncertainty among investors, bears strengthened their grip on the natural gas futures market Friday. Meanwhile, spot prices saw heavy discounts from coast to coast ahead of the weekend; the NGI Spot Gas National Avg. tumbled 22.0 cents to $1.860/MMBtu.
The Nymex July futures contract dropped 9.3 cents to settle at $2.454 after trading as low as $2.444 on the day. August settled at $2.460, a 9.7-cent decline, while September fell 9.9 cents to $2.450.
After rallying 5.1 cents on Wednesday, the last day of trading for the June contract, the front month plunged a combined 17 cents during Thursday’s and Friday’s sessions. The $2.454 settle price Friday roughly matches the lows recorded in late April, when the May contract settled as low as $2.455. Before that, the prompt month hadn’t settled below $2.500 since June 2016.
The Energy Information Administration (EIA) on Thursday reported a much larger-than-expected 114 Bcf injection into U.S. natural gas stocks for the week ended May 24, versus a 95 Bcf build recorded in the year-ago period and the five-year average 97 Bcf injection. Total Lower 48 working gas in underground storage stood at 1,867 Bcf as of May 24, 156 Bcf (9.1%) higher than year-ago levels but 257 Bcf (minus 12.1%) below the five-year average, according to EIA.
This week's 114 Bcf U.S. natural gas build came in a “whopping” 16% ahead of Tudor, Pickering, Holt & Co. (TPH) forecasts, analysts said, "helping reduce the deficit to the five-year average to only 12%, compared to 14% a week ago.
"The larger than forecast build could reflect somewhat of a catch-up print, as the prior two weeks came in a combined 15 Bcf below expectations.”
Injections are coming in "faster than in years' past, with this week's build 20% higher than the five-year average and 19% ahead of last year; on a weather adjusted basis the market continues to be 3 Bcf/d oversupplied,” the TPH team said.
"Focusing on regional storage, inventories in the East region now sit only 3% below the five-year average, while in the Mountain region, inventories remain outside of the five-year range (31% below the five-year average).”
TPH noted that U.S. liquefied natural gas (LNG) feed gas demand remained strong this week, with volumes averaging 5.8 Bcf/d "amid growing concerns around weakening LNG demand out of Europe.” TPH’s preliminary modeling for next week’s storage report is showing a 107 Bcf build, "in line with the five-year average for the week, which typically represents trough demand for the year."
This week’s injection implies the market was 5.3 Bcf/d looser than last year adjusting for weather, and the market has averaged 2.7 Bcf/d looser over the past four weeks, according to analysts with Raymond James & Associates.
Genscape Inc. viewed the figure as about 6.0 Bcf/d loose versus the five-year average when compared to degree days and normal seasonality.
Analysts with Jefferies LLC observed that injections have continued to run above average but were only around 18% above average in May compared to around 141% larger than average in April.
In terms of balances, “May production has averaged around 87.1 Bcf/d, just ahead of April’s record production of 86.9 Bcf/d,” according to the Jefferies team. “Production is up 7.0 Bcf/d year/year, the lowest year/year growth since November 2017. Haynesville production has continued its climb, averaging a new high of 11.4 Bcf/d thus far in May.
“Waha pricing is clearly still weighing on Permian production, which is down around 170 MMcf/d sequentially and at the lowest level since September 2018. Appalachia production, at 31.2 Bcf/d, is down slightly versus April at 31.3 Bcf/d.”
On the demand side, LNG feed gas flows have averaged 5.6 Bcf/d in May, up 2.6 Bcf/d year/year and topping the previous monthly record of 4.9 Bcf/d set in March, the Jefferies analysts said.
“Sabine Pass Trains 1-5, Corpus Christi and Cove Point all ran near capacity during the month,” analysts said. “Cameron flows ramped up to around 320 MMcf/d in May (about 500 MMcf/d over the last week), and initial flows started at Elba Island and Freeport.”
Fading Heat, Widespread Discounts
In the spot market, fading Southeast heat and generally comfortable temperatures across the Lower 48 contributed to widespread discounts on deals for weekend and Monday delivery.
“Recent record-breaking heat across the Southeast will ease through the weekend as upper high pressure weakens and shifts toward Texas,” NatGasWeather said Friday. “Much of the rest of the country will be quite comfortable with highs of upper 60s to 80s, although still with pockets of heavy showers.
In constrained West Texas, most locations posted hefty declines to drop firmly back into negative territory ahead of the weekend. El Paso Permian gave up 45.0 cents to average minus 47.0 cents.
Elsewhere, a number of locations across the eastern two thirds of the country posted discounts of a dime or more. In Appalachia, Dominion South slumped 10.5 cents to $2.100.
Scheduled maintenance on the Equitrans system upstream of the MarkWest Mobley processing plant in West Virginia could “significantly reduce receipts” starting Monday and continuing Wednesday, according to Genscape analyst Anthony Ferrara.
“Equitrans did not provide specific amounts as to how much gas will be restricted, but the impact will take place at Meter 24605,” which is associated with the Mobley facility, Ferrara said. This “will subsequently reduce operating pressures on the Equitrans Ohio Valley Connector (OVC) pipeline. With reduced pressures on the OVC line, Equitrans’ capability will be limited to deliver gas through the Plasma-OVC Compressor Station to Rover, Rockies Express and Texas Eastern (Tetco).
“Over the past seven days, receipts at Meter 24605 have averaged 534 MMcf/d and maxed at 543 MMcf/d, while flow through Plasma-OVC has averaged 625 MMcf/d and maxed at 665 MMcf/d.”
A force majeure event on May 19 affecting these two locations saw receipts at Meter 24605 drop by 400 MMcf/d and cut Plasma-OVC flows by 145 MMcf/d, Ferrara said.