Natural gas futures dropped close to a nickel Wednesday ahead of a government storage report expected to show the season’s first injection. Spot prices saw mostly small adjustments amid forecasts for generally moderate temperatures, and the NGI National Spot Gas Average finished down 2 cents at $2.36/MMBtu.
The June contract settled at $2.754 Wednesday, down 4.8 cents after trading as high as $2.811 and as low as $2.745. July settled at $2.791, down 4.6 cents.
Wednesday’s price action reversed a 3.9-cent gain from the day before, when the prompt-month traded as high as $2.820, testing the upper end of a long-standing trading range, according to analysts.
Estimates for Thursday’s Energy Information Administration (EIA) storage report point to the injection season officially getting underway this week -- about a month later than unusual.
A Reuters survey of traders and analysts on average called for EIA to report a 52 Bcf injection into Lower 48 gas stocks for the week ending April 27, with responses ranging from 40 Bcf to 68 Bcf. A Bloomberg survey produced a median build of 51 Bcf, with responses ranging from 40 Bcf to 62 Bcf. Last year EIA recorded a 68 Bcf injection during the period, while the five-year average is a build of 69 Bcf.
IAF Advisors analyst Kyle Cooper predicted a 53 Bcf injection, while Genscape Inc. called for the EIA to report a 55 Bcf injection. Intercontinental Exchange EIA storage futures settled Wednesday at an injection of 55 Bcf for the upcoming report.
Price Futures Group Senior Analyst Phil Flynn called for a build of 40 Bcf.
“I know I’m a little on the low end, but the low end is the place to be the last few weeks,” Flynn told NGI.
The market may need to see a smaller injection to avoid a move lower given moderate weather and strong production that’s expected to continue rising, according to Flynn.
“I think if we get a number anywhere near the five-year average it will get very bearish for this market, and I think the market’s preparing for the possibility that it’s going to go down,” he said.
NatGasWeather.com said it expects weather patterns to “remain neutral to bearish into the foreseeable future, with much larger injections to come...we now look to the first signs of widespread heat and see the southern U.S. playing out warmer than normal in late May, so if it were to continue into early June, cooling degree days could begin to take a bigger bite out of injections with increasing power burns.”
This week’s report should see the year-on-five-year storage deficit widen to around 550 Bcf, and “there should be some concerns” storage won’t refill at a fast enough clip to satisfy the market, the firm said. The reports for weeks three through seven of the current outlook hold the most significance, “and they better come in quite hefty or the markets could be disappointed.”
Turning to the spot market, Northeast prices were mixed Wednesday as forecasts called for some unusually warm -- though not particularly extreme -- temperatures for major population centers in the region.
Radiant Solutions was forecasting temperatures around 10-20 degrees above normal Thursday and Friday along the I-95 corridor from Washington, DC to Boston, equating to highs in the 80s to low-90s, with lows in the 60s.
In Appalachia, Dominion South tacked on 7 cents to $2.20 Wednesday, while Transco-Leidy Line shed 14 cents to $1.72 -- coinciding with reports of maintenance on the Leidy Line this week related to the Atlantic Sunrise expansion.
FERC’s order Tuesday authorizing the Rover Pipeline’s Market Segment, as well as its Vector Meter Station and Defiance Compressor Station, likely won’t increase total throughput capacity on the designed 3.25 Bcf/d project, according to Genscape.
“This in-service should allow around 1.3 Bcf/d of gas to be transported from Defiance to Vector, where Rover has approximately 950 MMcf/d of capacity reserved from their interconnect into the Michigan and Dawn area,” Genscape analyst Colette Breshears told clients Wednesday. Last week’s order approving the Mainline Compressor 3 and Mainline B segment “has not had a material impact” on the pipeline’s flows so far.
“The approval of the Vector/Market Lateral is not expected to affect the current upper bound of throughput volumes on the currently in-service Mainline A, which is expected to peak around 2 Bcf/d,” Breshears said. “In order to reach its full 3.25 Bcf/d capacity, Rover will need to bring on the remaining sections of Mainline B, which runs through central Ohio. Currently only one centrally located section of Mainline B has been approved for service.”
A February request to start up the Burgettstown Lateral to southwestern Pennsylvania has gone months without an affirmative response from FERC.
Rover finished bringing its first phase online at the end of last year and has recently been flowing more than 1.6 Bcf/d east-to-west across Ohio to interconnects with the Panhandle Eastern and ANR pipelines, according to NGI’s daily Rover Tracker.
In California, SoCal Citygate reversed the prior day’s losses, adding 21 cents to $3.62.
Two-day maintenance scheduled to start Thursday on the western part of El Paso Natural Gas’ (EPNG) South Mainline could impact more than 100 MMcf/d of volumes flowing to Southern California Gas (SoCalGas), according to Genscape analyst Joe Bernardi.
“Shut down checks at the Casa Grande station will lead to an operating capacity reduction of 107 MMcf/d at the CASA C point, which tracks westbound molecules on the intermediate pressure system of the South Mainline and has been flowing full over the last month,” Bernardi said. “Past disruptions here have sometimes corresponded with spikes in SoCal Border basis price.
“However, EPNG has also kept molecules flowing to SoCalGas by transferring gas from one pressure system to another...and by wheeling gas through its interconnect with Mojave and the southeasterly-flowing Line 1903.”
SoCalGas reported total system demand of around 2,561,000 Dth/d Tuesday, exceeding receipts of 2,372,000 Dth/d and forcing a net withdrawal from storage of 189,000 Dth/d.
Meanwhile, an administrative law judge for the California Public Utilities Commission (CPUC) on Wednesday issued a proposed decision that would, among other things, reject plans submitted by SoCalGas and San Diego Gas & Electric to build a new 47-mile, 36-inch diameter pipeline in San Diego County.
A force majeure event on NGPL’s system in South Texas could restrict about 85 MMcf/d of flows, according to Genscape analyst Vanessa Witte.
“NGPL declared a force majeure at CS 300 on Segment 22 from May 1-31, which was not initially expected to impact flows. However, due to horsepower issues at CS 300, nominations for southbound flow received north or east of CS 302, just upstream of CS 300, will be scheduled to 40% of primary firm as of May 3 and lasting until further notice,” Witte said.
Operating capacity through Segment 22 from Station 341 to Station 302 is expected to be reduced to around 150 MMcf/d from a prior 30-day average 233 MMcf/d, Witte said. During a similar event April 12-15, “nominations to NET Mexico dropped from an average of 288 MMcf/d to 172 MMcf/d.”
Genscape’s proprietary monitor of NET Mexico pipeline flows was showing a “modest decline” Wednesday but “not outside the range of normal intra-day fluctuations,” according to Witte.