A heat wave in Southern California helped drive natural gas spot prices higher on average for the week ended Friday, even as points throughout the Gulf Coast slid along with declines in futures; the NGI Weekly National Spot Gas Average added 8 cents to $2.70/MMBtu.
The biggest gainer on the week was SoCal Citygate, which jumped $1.57 to average $5.08. Triple digit temperatures moved in late in the week to send day-ahead prices spiking in the volatile and supply-constrained Southern California market.
Further upstream, the Rockies and West Texas producing regions also saw spot price gains amid the heat. Kern River jumped 48 cents on the week to $2.44, while El Paso Permian climbed 37 cents to $2.12.
Prices in the Northeast were mixed as recent hot temperatures along the East Coast began to moderate late in the week. Transco Zone 6 New York gave up a penny to average $2.96, while Algonquin Citygate finished 13 cents higher at $2.98.
Production growth continued to apply bearish pressure to futures during the week, which corresponded with discounts throughout much of Louisiana and Texas. Henry Hub shed a dime to average $2.86, and Houston Ship Channel slid 3 cents to $2.95.
Natural gas futures bulls gained back some ground Friday after taking it on the chin earlier in the week, even as a slight bearish miss from government storage data appeared to offer little in the way of support.
The August Nymex futures contract added 2.1 cents to settle near its intraday high at $2.858 Friday, but despite the bounce the prompt-month still finished firmly in the red for the week after opening Monday at $2.920. The September contract added 1.4 cents to settle at $2.826.
Bespoke Weather Services said Friday’s trading range was uncharacteristically narrow considering the release of the Energy Information Administration’s (EIA) weekly storage data. The firm described Friday’s gains as a weak bounce helped by storage data that generally confirmed market expectations.
“We have seen power burns begin to tighten again at these lower price levels, yet production at record levels continues to limit the impact of any tighter weather-adjusted demand and pressure the entire natural gas strip,” Bespoke said. “…A much weaker fall and winter strip reflects just how overwhelming production is expected to be, and with cool risks likely arising into the final third of July that would only be expected to put $2.75 in play sooner.
“…Tight power burns and low storage levels have helped keep the front of the strip bid for now, with medium-term intense heat also helping, but as soon as a more sustained cooler pattern looks likely we would see $2.75 tested, likely next week.”
Bulls hoping for a lean natural gas storage report from the EIA Friday left disappointed as it reported a net build on the higher side of average estimates. Still, futures prices stayed the course after briefly dropping on the news.
EIA, issuing its weekly report a day later than usual because of the Independence Day holiday, said Lower 48 natural gas stocks saw a net 78 Bcf build for the week ending June 29, versus a 60 Bcf injection recorded a year-ago and a five-year average 70 Bcf build.
The number also topped major survey averages by around 3 Bcf, a reversal from the prior week’s bullish miss(although that report also included a bearish revision to stocks for the week ended June 15).
Immediately after the 10:30 a.m. ET release of the injection figure, August Nymex futures shed about 2 cents to reach as low as $2.826, testing what analysts have pegged as a key support area for the prompt month. But prices bounced back within minutes, and by 11 a.m. ET August was trading around $2.848, up about 1.1 cents from Thursday’s settle and in line with prices prior to the open.
Total working gas in underground storage stood at 2,152 Bcf as of June 29, versus 2,869 Bcf last year and five-year average inventories of 2,645 Bcf. Week/week the year-on-year deficit shrank from minus 735 Bcf to minus 717 Bcf, and the year-on-five-year deficit narrowed from minus 501 Bcf to minus 493 Bcf, EIA data show.
By region, the Midwest and East each recorded a net build of 30 Bcf for the week, while the rest of the country saw smaller inventory gains, according to EIA. The Mountain region saw a 6 Bcf build, as did the Pacific. In the South Central, which also finished with a net 6 Bcf build, 13 Bcf was injected into nonsalt, offsetting a 7 Bcf withdrawal from salt.
Analysts with Jefferies LLC said Friday a return to the five-year average storage level “is unlikely this summer, as production would likely need to average around 9.5 Bcf/d higher year/year (y/y) to reach 3.8 Tcf.
“…U.S. natural gas production reached 80 Bcf/d for the first time in late June and has maintained this level for eight of the past nine days,” the Jefferies team said. “June production averaged 78.7 Bcf/d, up 0.6 Bcf/d sequentially and up 6.7 Bcf/d y/y.”
Appalachian production has increased about 0.5 Bcf/d from late June to early July, while Permian Basin natural gas output has remained flattish since March at around 7.1-7.2 Bcf/d, according to the firm.
“If production continues at the same y/y growth rate as June for the remainder of the refill season, we estimate that the season will end with storage at 3.4 Tcf (about 9% below average),” the Jefferies team said. “For storage to reach 3.8 Tcf, we estimate that production would need to average 9.5 Bcf/d higher y/y for the remainder of the refill season (this would imply production averaging 82.3 Bcf/d, well above current levels).
“In these scenarios, we assume power demand of plus 2.0 Bcf/d y/y, hold exports flat with recent levels and assume no y/y changes in residential/commercial or industrial demand,” according to the analysts. “The current storage level could lead to higher near-term natural gas prices, as a higher price will be needed to incentivize more power generation to switch back to coal and allow more gas to flow into storage.”
Spot prices for weekend and Monday delivery saw heavy declines across much of the Lower 48; points in Southern California pulled back as a heat wave in the region was expected to moderate somewhat over the weekend, while cooler conditions drove discounts in the East. The NGI National Spot Gas Averagefell 12 cents to $2.60/MMBtu.
After adding more than $4 day/day Thursday, SoCal Citygategave back $2.87 Friday to head into the weekend averaging $5.41, still a substantial premium to surrounding locations. The price spikes for SoCal Citygate likely came as no surprise to those that have been watching the volatile trading point closely, as a heat wave moving into the region Friday put the supply-constrained Southern California Gas Co. (SoCalGas) system to the test.
Radiant Solutions forecast Friday’s high in Burbank, CA, to reach 110 degrees, with average temperatures around 18.5 degrees hotter than normal. Saturday’s high was expected to again reach triple digits at 103, with highs expected to fall back into the 90s by Sunday and Monday.
SoCalGas reported total estimated system sendout for Friday at 2.887 million Dth/d, up from 2.453 million Dth/d on Thursday and exceeding estimated total receipts of just above 2.7 million Dth/d. The utility was expecting demand to remain around 2.6-2.8 million Dth/d over the weekend and into Monday.
In the Northeast and Appalachia, calls for less intimidating temperatures along the East Coast over the weekend helped the put the chill on spot prices. Radiant Solutions was calling for highs in the upper 70s and 80s in Boston and New York City over the weekend, a reprieve from a recent stretch of temperatures consistently climbing into the 90s in the East.
Prices also weakened Friday across the Midwest, where Radiant was calling for temperatures over the weekend to hover around normal or slightly below normal in cities like Chicago and St. Louis. The declines included a 9-cent drop at Chicago Citygate, which averaged $2.61. In the Midcontinent, NGPL Midcontinent finished 11 cents lower at $2.39.
Beginning Monday and extending through July 24, Natural Gas Pipeline Co. of America’s (NGPL) Segment 17 in Cass County, TX, in its TexOK Zone could see capacity restrictions because of maintenance, according to Genscape Inc. analyst Vanessa Witte.
“This could restrict firm transports into Segments 26 and 27 during this time,” Witte said. “Segment 17 flow, taken at ”AG Line-Texas Segment,’ has averaged 350 MMcf/d over the prior 30 days, with a max of 456 MMcf/d. Northbound flow on Segment 27 has averaged only 62 MMcf/d, while southbound flow onto Segment 26 has averaged 990 MMcf/d.”
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