- August Nymex futures off 3.6 cents to $2.251; September down 3.5 cents to $2.228
- Upcoming EIA report “looks to be another bullish number, as power gen pushes 40 Bcf/d” and liquefied natural gas feed gas demand “continues its strength, averaging 4.9 Bcf/d for the week”: TPH
- Benchmark Henry Hub tumbles 8.5 cents to $2.275
Natural gas futures prices sold off again Friday to cap off a decidedly bearish week, with the latest forecasts not promising enough summer cooling demand to appease a well-supplied market. With the intense and widespread heat expected to subside after the weekend, spot prices sold off throughout the Lower 48; the NGI Spot Gas National Avg. tumbled 16.5 cents to $2.010/MMBtu.
The August Nymex futures contract dropped 3.6 cents to settle at $2.251, trading in a range from $2.242 up to $2.300. September fell 3.5 cents to $2.228, while October settled at $2.256, down 3.4 cents.
The midday Global Forecast System (GFS) data Friday came in slightly cooler trending for the upcoming week but slightly hotter for the start of August, according to NatGasWeather. A comfortable pattern advertised for the northern portions of the country from late July into early August kept the pattern from looking bullish Friday.
“We do expect national daily” cooling degree day (CDD) totals “are likely to be above normal to start August, but they need to be much above normal to intimidate, and that would require hotter trends,” NatGasWeather said. This is “possible over the weekend, as we view the risk biased toward hotter trends versus cooler trends. But will it really be hot enough to induce a weather-driven rally? Not likely unless there were significantly hotter trends.”
Meanwhile, the Energy Information Administration (EIA) on Thursday reported a 62 Bcf build into U.S. natural gas stocks for the week ended July 12, higher than the 46 Bcf build for the year-ago period but slightly below the five-year average of 63 Bcf. This week’s report marks the first below-average build since injections began in March, EIA historical data show.
Total Lower 48 working gas in underground storage stood at 2,533 Bcf as of July 12, 291 Bcf (13.0%) above year-ago levels but 143 Bcf (minus 5.3%) below the five-year average, according to EIA.
“Like Joe DiMaggio’s 56-game hit streak, eventually all streaks come to an end, and this week we ended the above-normal build streak (barely),” said analysts with Tudor, Pickering, Holt & Co. (TPH). “Barry impacts continue to be felt as Gulf of Mexico outputs are the primary driver behind dry gas volumes down around 2.3 Bcf/d from peaks achieved a week prior.
The upcoming EIA report “looks to be another bullish number, as power gen pushes 40 Bcf/d” and liquefied natural gas feed gas demand “continues its strength, averaging 4.9 Bcf/d for the week,” the TPH team said. “However, what this means for pricing is hard to say, as the market is in a three-way tug-of-war with bullish near-term fundamentals pulling against a bearish 2020 outlook, with a third force being applied from falling oil prices, which could drastically alter associated gas growth” should West Texas Intermediate prices drop below $50/bbl.
Genscape Inc. analysts viewed the 62 Bcf injection as indicating the market is about 2.0 Bcf/d loose versus the five-year average when compared to degree days and normal seasonality.
At current gas prices, average power burns for summer 2019 could finish ahead of the record levels set last summer, even with a “significant decline” year/year in CDDs, Genscape analyst Eric Fell said.
“This dynamic has already been in play this summer as seen with June power demand up approximately 1.5 Bcf/d despite 42 fewer CDDs for the month,” Fell said. “All else being equal, the decline in CDDs versus last June should have led to a decline in power demand of approximately 2 Bcf/d, but instead we saw an increase in gas demand of more than 1 Bcf/d. This means that, compared to last June, gas burn per CDD was up more than 3 Bcf/d.”
The increase in power burns per CDD this year has been driven by price, with June 2019 gas prices averaging nearly 60 cents lower compared to the year-ago period, according to Fell.
“Gas prices have actually been a stronger driver of gas demand than summer weather over the past 10 years,” he said. “Structural shifts have also been important, as we have retired coal plants and brought online new combined cycle gas plants. In 2018 we saw a particularly large shift in gas demand versus coal due to large changes in the power stack.”
Despite some of the hottest conditions of the summer to-date spread across the eastern two thirds of the Lower 48, the price reaction from the spot market had been muted heading into Friday’s session. With the sweltering conditions expected to dissipate early in the upcoming work week, deals for weekend and Monday delivery saw hefty discounts for most regions. Benchmark Henry Hub tumbled 8.5 cents to $2.275.
Over the weekend, NatGasWeather called for “hot high pressure” to strengthen across much of the country, increasing highs into the mid-90s from the Midwest to the East Coast. Highs were also expected to reach the 90s across the southern and central portions of the Lower 48, resulting in “very strong national demand, aided by very humid conditions.”
By the start of the upcoming work week, the forecaster called for showers and cooling to sweep across the Great Lakes and East.
“This will ease highs back into the 80s over these critical regions for lighter demand needs,” NatGasWeather said. “Cooling will also spread down the Plains into Texas and the South, dropping highs several degrees into the upper 80s to lower 90s.” In total, the pattern for the week ahead should result in “much lighter national demand.”
With cooler conditions expected after the weekend, prices headed lower throughout the Midwest, where Joliet shed 13.5 cents to $2.080. Elsewhere, East Coast locations also saw discounts. Transco Zone 6 NY slid 17.5 cents to $2.265. On the West Coast, meanwhile, PG&E Citygate shed 14.5 cents to $2.520. Further south, SoCal Citygate plunged 41.5 cents to $2.175.
A critical Southern California Gas (SoCalGas) import line was scheduled to return to service over the weekend, but that wasn’t expected to result in a change to overall import capacity, Genscape analyst Joe Bernardi said Friday.
“The L235 line, which brings gas west on SoCalGas from interconnects with El Paso Natural Gas and Transwestern, has been out of service since an explosion on Oct. 1, 2017,” Bernardi said. “SoCalGas has been working to restore it to normal operating pressure over the last several months but has been discovering new leaks on the line during testing.”
The latest maintenance schedule as of Friday showed L235 returning to service Sunday (July 21), but “there is some risk that this date gets pushed back again, in the event that further testing and remediation is needed.”
Assuming L235 returns to service as scheduled, it won’t result in an immediate increase in firm operating capacity, since once SoCalGas brings L235 back online it “plans to take the adjacent L4000 down for its own round of testing,” according to Bernardi.
The first increase in capacity through this area isn’t expected until the end of August, the analyst said.