Natural gas futures rallied into the front month expiration Wednesday, with forecasters pointing to colder medium-range trends that could encourage the bulls as the market turns its attention to the January contract. In the spot market, weakness in West Texas continued as moderating forecasts saw Mid-Atlantic and Southeast prices pull back; the NGI National Spot Gas Average added 12.0 cents to $4.465/MMBtu.
The December Nymex contract rolled off the board at $4.715, up 45.3 cents on the day after trading as high as $4.806. January settled at $4.699, up 40.7 cents. February added 37.7 cents to settle at $4.538, while March settled at $4.219, up 31.0 cents.
Bespoke Weather Services attributed some of the gains earlier Wednesday to overnight weather data that had increased heating demand expectations and strong prices in the physical market.
“We did expect to see some upside” on Wednesday, “given the December expiry and recent strong physical prices, but what followed was surprising as it appeared a major player had gas liabilities for December, forcing them to buy up the December contract dramatically into expiry,” Bespoke said. Model guidance that intensified cold risks through the first week of December and delayed the start of warmer temperatures expected to arrive around Dec. 10 “likely added fuel to the fire in the run-up, with prices not reversing as much post-expiry as we would have expected.
“Still, we struggle to justify prices above the $4.50 level right now even with significant medium-range cold given expectations that beyond Dec. 10 we see at least a temporary easing of the pattern. Though that has been thrown weakly into question, there remains strong atmospheric support for it,” according to the forecaster.
Meanwhile, estimates for this week’s Energy Information Administration (EIA) storage report, due on Thursday, showed market participants expecting a larger-than-average withdrawal for the week ended Nov. 23.
A Reuters survey of traders and analysts showed respondents expecting an average 77 Bcf pull for the week, with a range of minus 62 Bcf to minus 105 Bcf. A Bloomberg survey produced a median withdrawal of 82 Bcf, with predictions ranging from minus 60 Bcf to minus 88 Bcf. Intercontinental Exchange EIA financial weekly index futures settled Tuesday at a withdrawal of 65 Bcf.
Energy Aspects issued a preliminary estimate for a 63 Bcf pull from U.S. gas stocks for this week’s report.
“We expect the withdrawal rate to be cut nearly in half” for the latest report period, the firm said. Though gas-weighted heating degree days were only marginally lower week/week (w/w), “a 4.0 Bcf/d w/w giveback in the power sector combined with a holiday impact in the industrial sector have served to dampen demand by some 9 Bcf/d w/w.”
On the supply side, a 0.7 Bcf/d increase in production along with “marginal contributions” from liquefied natural gas sendout and net trade with Canada increased total supply by close to 1.0 Bcf/d w/w, according to Energy Aspects.
Last year, EIA recorded a 35 Bcf withdrawal for the period, and the five-year average is a withdrawal of 49 Bcf.
More Free Gas In West Texas
Physical prices in constrained West Texas continued to come under pressure Wednesday as prices strengthened across most regions. Meanwhile, expectations for moderating temperatures helped ease prices in the Mid-Atlantic and Southeast.
“Snows across New York and New England should persist into Thursday as a pair of surface lows merge and deepen offshore Maine,” the National Weather Service (NWS) said Wednesday. “...Temperatures across New England will remain below normal through Friday with some moderation expected late in the week.”
Radiant Solutions was calling for temperatures along the Interstate 95 corridor to gradually warm into the weekend. Washington, DC, was expected to see lows rise into the low 40s and 50s by Saturday and Sunday from the low 30s Wednesday. Further south, Atlanta was expected to see lows in the upper 20s Wednesday warm into the 40s and 50s by the end of the work week, according to Radiant.
In the Rockies, Northwest Sumas remained volatile, jumping $5.285 to average $17.055 amid ongoing constraints on supplies flowing south into the Pacific Northwest on Enbridge Inc.’s Westcoast system. The Westcoast pipeline had a system-wide operational flow order in effect Wednesday, with the operator citing reduced capacity on its T-South segment that stretches south across British Columbia to the U.S.-Canadian border.
“A wet, active pattern will continue for the West over the next few days, particularly near northern California,” the NWS said. “A pair of low pressure systems will move into the West early Thursday and late Friday.” Heavy snowfall is expected for higher elevations of the Sierra Nevada mountains, including “localized amounts of up to three feet by Friday morning.
“...By Friday, precipitation will shift mostly to the higher terrain of the Great Basin with some lingering showers and higher elevation snow occurring in California and parts of the Pacific Northwest. Because of the recent burn scars and expected heavy rainfall over several days, flash flooding is a concern for parts of California.”
Meanwhile, in West Texas, Waha averaged 45.5 cents, down 19.5 cents on the day, although there were no reports of negative transactions. The low price recorded at Waha Wednesday was zero, improving on Tuesday’s low of negative 25.0 cents.
As supply growth in the Permian Basin has overwhelmed takeaway capacity, the long-term trend in spot basis differentials showed West Texas locations like Waha and El Paso Permian have traded at an increasingly wide deficit to benchmark Henry Hub.
As of Tuesday’s trading, year-to-date Waha has averaged about $1.035 back of Henry Hub, compared to an average basis of roughly minus 27.0 cents for the comparable 2017 period, an analysis of Daily GPI historical data shows.
What’s more, the widest negative differentials in 2018 have been observed since September. On the Sept. 19 trade date, Waha prices averaged $2.45 cents back of Henry. With the broad strength observed in physical and futures markets since the start of the heating season, the crushingly low spot prices in West Texas have stood in even sharper contrast. On Tuesday, Waha’s differential to Henry Hub ballooned to a whopping minus $3.67.
“Counter to the broader natural gas market, Permian prices have plunged in recent trading as the Waha hub averaged under $1.00/Mcf over the last three days,” Tudor, Pickering, Holt & Co. (TPH) analysts said. "While a limited sample size, we have long anticipated regional gas prices approaching zero (and potentially negative), as relatively price-agnostic supply pressures limited pipeline takeaway.”
Still, while production has been on the rise in the Permian, the rate of supply growth hasn’t matched the rate of decline in prices, according to Genscape Inc. senior natural gas analyst Rick Margolin.
Margolin said it’s possible disruptions following an explosion late last week at Energy Transfer’s Waha gas processing plant in Pecos County, TX, exaggerated some of the price action observed in the region early this week. An emergency management official in Pecos County confirmed to Daily GPI that an explosion occurred about mid-morning last Friday near Coyanosa, TX. Coyanosa is near the Waha hub.
Energy Transfer spokeswoman Alexis Daniel also confirmed the explosion. “The area was isolated and contained and the fire was allowed to safely burn itself out,” she said. “We are currently conducting our investigation and are working on the needed repairs. We were able to divert much of the gas to other facilities in order to minimize disruption to deliveries.”
As of Wednesday, Margolin said it wasn’t clear whether Energy Transfer had completely restored operations following the explosion. “There has also been a marked uptick in flaring throughout the basin through this month,” he said.
Genscape’s Spring Rock production estimates on Wednesday showed production volumes in the Permian near 8.6 Bcf/d, with the previous five days posting volumes well above 9 Bcf/d. That’s about 150 MMcf/d higher than October 2018 volumes and close to 1.6 Bcf/d more than volumes recorded in November 2017, according to Margolin.
The TPH supply model is forecasting 2.2 Bcf/d of residue gas growth between now and the start up of Kinder Morgan’s Gulf Coast Express project, which would move gas supply to the Texas coast and potentially south to Mexico.
In the interim, TPH analysts said they view the Old Ocean revamp underway in Texas to move more gas south by Energy Transfer LP and Enterprise Product Partners LP as likely to "have little impact, as its 160 MMcf/d equates to less than one month of run-rate production growth.”
A “more meaningful” bump to takeaway capacity should come from the expected completion in March of Fermaca’s La Laguna-Aguascalientes and Aguascalientes-Guadalajara pipelines,” said the TPH team, which would connect Permian gas exports to industrial demand in central Mexico.