- May rallies 7.9 cents to $2.739 after losing 7.9 cents a day earlier
- Possible delayed reaction to “quite bullish” EIA storage data, says Bespoke
- Recent strength in crude prices lifts 2019 production forecast: Genscape
- Spot prices down across most regions, West Texas mixed
Natural gas futures reversed course Friday to completely erase Thursday’s sharp selloff, with storage deficits and a slow start to injection season helping the bulls make their case. In the spot market, forecasts for moderating temperatures by Monday in key Midwest and East Coast markets curbed interest in three-day deals; the NGI National Spot Gas Average fell 19 cents to $2.42/MMBtu.
The May contract rallied 7.9 cents to settle at $2.739 Friday in a perfect mirror of Thursday’s 7.9-cent decline. June settled 7.2 cents higher at $2.767.
Despite more accelerated moves Thursday and Friday, natural gas couldn’t break out of the recent range of roughly $2.55-2.80 that has held for weeks, Powerhouse President Elaine Levin told NGI.
“If I take a look at the 20-day moving average...the mean’s been about $2.70 and we have not really been able to pull excitingly away from that since the big decline we had in February,” Levin said. “The market just seems very comfortable where it is. Perhaps the fact that we’re still withdrawing has held the support level, but the production potential is keeping us from breaking the resistance.”
Bespoke Weather Services said the driving factor behind Friday’s rally, while not immediately clear, appeared to be the tighter-than-expected storage data from the day before.
Thursday’s Energy Information Administration (EIA) “storage print was quite bullish, and this is now the second week in a row where we have seemed to have a one day delay in the reaction to a bullish EIA miss,” Bespoke said. “Heading into the weekend then we note that confidence is a bit lower than average; cash prices have remained the primary bullish catalyst for natural gas prices and those are expected to ease through next week.”
EIA reported a 36 Bcf withdrawal from Lower 48 gas stocks for the week ending April 13, an unusual pull from inventories during injection season thanks to uncharacteristically cold weather during the period. Last year, 47 Bcf was injected, and the five-year average is a build of 38 Bcf.
On a weather-adjusted basis the gas market “returned to less than 1 Bcf undersupplied, ending a two-week trend of oversupply,” analysts with Tudor, Pickering, Holt & Co. (TPH) said Friday. “Counter-seasonal draws are expected to continue one more week, with preliminary estimates around 12 heating degree days above five-year averages,” implying undersupply of more than 2 Bcf/d.
“Long-term, however, expect temperatures to be warmer as we transition into injection season,” the TPH analysts said. “Mexican exports remain below January/February levels” presenting “a red flag for those betting on Mexican demand to bail out the Permian.” Meanwhile, liquefied natural gas exports are “ramping, though somewhat volatile,” as Dominion Energy’s Cove Point export project “moves toward sustained operations.”
The EIA storage withdraw “was driven by the lingering cold, generating total degree days 47 greater than the five-year average, and marks the latest a withdraw has been reported since at least 2010,” Genscape Inc. analyst Eric Fell said Friday. “Power demand was much stronger this week versus the prior two weeks. That was not reflected in pipeline nomination data, but was apparent with our power plant monitors and” independent system operator “data. Also, net exports were stronger this week versus the prior two weeks.”
Despite the bullish report, forward initially on Thursday “went the other way on what we assume is related” to a delay for the liquefied natural gas (LNG) export project, Freeport LNG, according to Fell. The terminal’s delay in starting up could reduce LNG exports by an average of 600 MMcf/d for the upcoming winter and by 1.3 Bcf/d in the summer of 2019.
After the recent cold weather across the Midwest and Northeast, Societe Generale analyst Breanne Dougherty said she expects “the net storage injection pace this month to be under 2 Bcf/d. This is the lowest level in our history set -- very low compared to the five-year average of 7 Bcf/d.”
According to Dougherty, Societe Generale expects 3Q2018 prices to average $3.00, with 1Q2019 presenting a potential “buy opportunity at the moment given our expectation that if bullish sentiment is to make its way into the market this summer, there will be a significant number of participants” flocking to those contracts, which could drive up prices “even if only for a few months time.”
Societe Generale’s forecast for end-of-October inventories has been coming in around 3.55-3.65 Tcf, versus 3.78 Tcf last year, she said.
On the supply side, the U.S. rig count continued to climb for the week ended Friday, adding five units thanks to oil drilling gains focused in the Permian Basin, according to data from oilfield services (OFS) giant Baker Hughes Inc.
The upward trajectory in the U.S. oil rig count comes as crude prices have been on the rise. The May Nymex West Texas Intermediate (WTI) contract settled 9 cents higher at $68.38/bbl Friday.
The recent strengthening in crude prices puts more downward pressure on gas forwards given the prospect for associated gas growth, according to Genscape analyst Rick Margolin.
The crude oil prompt month settlement at $68.29/bbl Thursday at the time marked “its highest level since November 2014,” Margolin said in a note to clients Friday.
“The rally is being driven by a variety of news and data points, including (but not limited to): a reported drawdown in U.S. storage inventories bringing levels below five-year averages, strong refinery and export demand, worries about geopolitical issues including strikes on Syria potentially pulling oil producing Russia and Iran into the mix, and reports this week that” the Organization of Petroleum Exporting Countries (OPEC) “has been very successful hitting its targets for production cuts.”
The near-term nature of a lot of these issues has made the curve “notably inverted through late 2023,” but “most longer-dated forwards have also risen and WTI futures never drop below the $50/bbl mark through 2026,” he said. Genscape’s breakeven analysis indicate producers in gassy, oil-focused plays would be “well in the money at or above $50/bbl, which is more or less confirmed” by analysis of hedging activity.
The strong crude oil prices are driving increases in the latest updates to Genscape’s Spring Rock gas production forecast. For the week ending April 13, “a $1.07/bbl gain in the 2019 crude price helped drive a 0.35 Bcf/d increase in the gas production forecast,” Margolin said. “And the latest $3-plus gain in crude looks to contribute to the addition of nearly 0.7 Bcf/d to our summer 2019 gas production forecast.”
Turning to the spot market, prices weakened across most regions, including a second straight day of heavy losses in the Midwest and Northeast following weather-driven gains earlier in the week.
Radiant Solutions was calling for temperatures in Chicago to remain colder than average over the weekend, with highs in the 50s and lows in the upper 30s, before warming to near normal by Monday. Further east, Radiant was calling for cooler-than-normal conditions to continue through the weekend in cities including New York and Boston, but milder versus Friday’s temperatures.
In the Midwest, Chicago Citygate fell 17 cents to $2.54, while in the Northeast, Algonquin Citygate tumbled $1.85 to $3.03.
In the West, SoCal Border Average gave up 13 cents to $1.87. Meanwhile, SoCal Citygate dropped 61 cents to average $2.25, ending a roughly two-week stretch of premium-pricing there amid ongoing import-constraints for Southern California Gas Co. (SoCalGas).
SoCalGas was forecasting weekend demand on its system to hover around 2 Bcf/d before climbing to around 2.3 Bcf/d Monday. That’s versus demand of close to 2.6 Bcf/d on Thursday, according to the utility. SoCalGas was forecasting system receipts of a little over 2.5 Bcf/d over the next several days.
Further upstream, points in the Rockies generally dropped by a dime or more, while West Texas prices were mixed. El Paso Permian dropped 5 cents to $1.52, while Waha gained 5 cents to $1.70.