- January Nymex futures down 3.4 cents to $4.612; February settles 6.3 cents lower at $4.419
- “All weather models continued to show a mild ridge setting up across much of the eastern two thirds of the country Dec. 12-15,” says NatGasWeather
- Production topped 87 Bcf/d Friday, top-day estimate more than 1.22 Bcf/d above prior week’s average: Genscape
- SoCal Citygate spikes $6.620 to average $13.625
Natural gas futures bulls lost ground Friday as forecasters pointed to a mid-December break from cold temperatures across much of the country. Physical prices continued to strengthen across the West, especially in Southern California, while deals for weekend and Monday delivery were generally discounted across the eastern two thirds of the country; the NGI Spot Gas National Avg. increased 14.0 cents to $4.670/MMBtu.
After trading as low as $4.473 around lunchtime on the East Coast Friday, January Nymex futures recovered to settle 3.4 cents lower at $4.612. The February contract settled 6.3 cents lower at $4.419, while March skidded 14.2 cents to $4.014.
NatGasWeather said the timing of the spike into Friday’s settle might have been caused by “too many shorts trying to exit before the weekend break,” or possibly traders willing to take on risk hoping that mild trends showing up in forecasts for mid-December Friday wouldn’t play out as expected.
“The afternoon European model was little changed” through the upcoming week, but it trended colder with a weather system across the Great Lakes and Northeast Dec. 8-11, opposite the milder trends advertised by the Global Forecast System, the forecaster said. “All weather models continued to show a mild ridge setting up across much of the eastern two thirds of the country Dec. 12-15 for lighter demand.
“...For the weekend break, if the ridge shows signs it will only last through Dec. 16-17, the markets could see that as bullish” and indicating the milder trends won’t last, the forecaster said. “But if it looks to hold through Dec. 20, the markets could see that as lasting too long.”
Meanwhile, the Energy Information Administration (EIA) reported a 59 Bcf withdrawal from natural gas stocks Thursday that missed well to the bearish side of expectations. The 59 Bcf withdrawal for the week ended Nov. 23 compares to a year-ago pull of 35 Bcf and a five-year average withdrawal of 49 Bcf. Total Lower 48 working gas in underground storage stood at 3,054 Bcf as of Nov. 23, according to EIA, down 644 Bcf (17.4%) from a year ago and 720 Bcf (19.1%) below the five-year average.
“Weather-adjusted, the market was 3.5 Bcf/d oversupplied after last week’s brief stint in an undersupplied market,” analysts with Tudor, Pickering, Holt & Co. (TPH) said. “Though we believe the natural gas market will remain materially oversupplied over the short-term (and medium-term), the past few weeks have illustrated demand’s sensitivity to weather.”
The 10-14 day forecast continues to show frigid conditions for the eastern United States and the Northeast in particular, the TPH team noted.
“Having said that, supply continues to be robust, as U.S. dry production was reported as roughly 88.4 Bcf/d, or about 1.5 Bcf/d higher than two weeks ago (including the roughly 0.5 Bcf/d upward revision to production for the week of Nov. 15),” according to the TPH analysts.
Genscape Inc. analysts Margaret Jones and Eric Fell said the 59 Bcf pull indicates the market was about 4.0 Bcf/d loose versus the five-year average when compared to degree days and normal seasonality. Total power generation fell about 23 average GWh versus the previous week amid warmer temperatures and the impact from the Thanksgiving holiday.
“However, this week also saw clear evidence of coal switching in the power stack composition...despite the overall decline in loads, coal generation was actually up around 4 average GWh week/week (w/w),” Jones and Fell said. “This increase in coal generation even as loads declined meant gas generation fell even harder than what the overall drop in power loads/thermal gen would normally have implied.”
Strong physical market prices for the week helped to “push gas from around 55% of thermal generation down to about 50%,” contributing to an estimated 5.4 Bcf/d less gas burn w/w.
On the supply side, Genscape’s SpringRock daily production estimates as of Friday showed yet another daily record high, with output topping the 87 Bcf/d mark, according to senior natural gas analyst Rick Margolin.
The top-day estimate Friday was more than 1.22 Bcf/d above the prior week’s average, Margolin said.
“Texas volumes are up around 0.64 Bcf/d on a surge in intrastate interconnect receipts. Gulf of Mexico output is showing a 0.35 Bcf/d increase with resolution of an earlier-week outage in Mississippi Canyon,” he said. “Northeast production is up an estimated 0.31 Bcf/d, driven primarily by increased receipts in Northeast Pennsylvania, with Tennessee Gas Pipeline and Transco posting increases of 0.15 Bcf/d and 0.13 Bcf/d respectively.”
Estimates for Permian receipts were also higher w/w by 0.16 Bcf/d, according to Margolin.
Strength Out West, Moderation Further East
Across the Rockies and California, where a number of locations were already trading at elevated premiums, prices continued to ratchet higher Friday. The volatile SoCal Citygate spiked $6.620 to average $13.625.
SoCal Citygate, already posting substantially higher and more volatile prices so far this winter compared to last year, is set up for even more volatility over the next week or so, according to Genscape analyst Joe Bernardi.
The Southern California trading point has experienced stronger basis and more volatility due to a combination of higher demand and “ongoing restrictions on pipeline import capacities at a time when the market has to be conservative with storage” because of regulatory limits on the Aliso Canyon facility, the analyst said. Regional demand, including Southern California Gas (SoCalGas), Kern River, El Paso Natural Gas and Mojave, averaged 3.2 Bcf/d in November, about 150 MMcf/d higher year/year.
“More gas-fired power generation has had to move to within the market due to lower power imports from the Pacific Northwest,” Bernardi said. “In addition, outright gas demand has been buoyed by population-weighted daily average temperatures coming in slightly colder than last November. Recent daily average population-weighted temperatures have dipped into the lower 60 degree range versus normal for this time of year at 69 degrees.”
SoCalGas system demand on Friday topped 2.7 Bcf/d for the first time this winter, with regional demand up near 3.6 Bcf/d, also the highest for the winter to date, according to the analyst.
“While SoCalGas system storage inventories are entering the winter in better shape than in the last two winters, restrictions continue to remain in place at the Aliso Canyon storage facility,” Bernardi said. “This will once gain place heightened dependence on import pipelines, though capacity remains restricted on several critical paths.” SoCal Citygate will likely see “heightened potential for sustained volatility given regional weather forecasts are calling for the current block of colder weather to linger” until late in the upcoming week.
“Across the Western U.S., a new storm system will arrive across the Pacific Northwest, which will bring another round of heavier precipitation to especially southwest Oregon and northern California” Friday night and Saturday, the National Weather Service said. “This will bring a new round of heavy snowfall for the Sierra Nevada and also portions of the Cascades. In fact, additional snowfall totals of one-to-two feet can be expected going through Saturday.
“By Sunday, all of this Pacific moisture and energy will traverse the Great Basin and the central and southern Rockies. The result will be locally heavy snowfall over the higher terrain. Areas likely to see the heaviest amounts will be the Wasatch of Utah and the San Juan mountains of southwest Colorado where over 1 foot of new snow is possible.”
Enbridge Inc. notified shippers Friday that it continues to advance plans to restore capacity on its Transmission South segment following the Oct. 9 rupture near Prince George, British Columbia (BC) that has disrupted flows and roiled regional markets. Enbridge said it has secured an order from the National Energy Board to increase capacity at its Huntingdon Delivery Area to around 1.4 Bcf/d. That would amount to an increase of roughly 300 MMcf/d based on previous notices to shippers estimating Huntingdon capacity.
“The capacity on the system will be gradually increased over the next few days, and there may be daily fluctuations while Enbridge does the work required to increase capacity and stabilize the system,” the operator said Friday.
Meanwhile, Westcoast flows into Alberta from BC were expected to be curtailed as part of a three-day maintenance event starting Saturday, according to Bernardi.
“A cleaning tool run is cutting delivery capacity at Gordondale to 109 MMcf/d Saturday and Sunday (Dec. 1-2), with a drop to zero on Monday (Dec. 3),” the analyst said. “An average of 144 MMcf/d has flowed here from Westcoast onto NGTL and Alliance” during the month of November.
Prices sold off across much of the eastern two thirds of the Lower 48 Friday with temperatures expected to moderate over the weekend. In the Northeast, Transco Zone 6 NY fell 11.0 cents to $4.355, while further upstream in Appalachia, Dominion South eased 4.0 cents to $4.160.
A mild break was expected to dominate the southern and eastern United States over the weekend, bringing above normal temperatures including highs in the mid 40s to 60s in the Northeast and in the 70s to lower 80s across Texas and the South, NatGasWeather said Friday.
“However, at the same time a strong weather system will spin up over the central U.S. with increasing rain and snow, while also drawing in cold Canadian air,” the forecaster said. This sets up the week ahead to be “quite cold over much of the country as below normal temperatures spread across most regions.”