Northeast producers are about to get a new path to target LNG export demand at Cheniere Energy’s Sabine Pass LNG terminal. Cheniere in late December received federal approval to commission its new Sabine Pass lateral—the 2.1-Bcf/d East Meter Pipeline. Also in late December, Williams indicated in a regulatory filing that it anticipates a February 1, 2017 in-service date for its 1.2-Bcf/d Gulf Trace Expansion Project, which will reverse southern portions of the Transcontinental Gas Pipe Line to send Northeast supply south to the export facility via the East Meter pipe. Today we provide an update on current and upcoming pipelines supplying exports from Sabine Pass.
There’s good reason to believe that the international LNG market has turned a corner, with demand and LNG prices on the rise and with a number of new LNG-import projects being planned. That would be good news for U.S. natural gas producers, who know that rising LNG exports will boost gas demand and support attractive gas prices. It also would help to validate the wisdom of building all that liquefaction/LNG export capacity now nearing completion. Today we look at recent developments in worldwide LNG demand and pricing and how they may signal the need for more LNG-producing capacity in the first half of the 2020s.
The CME/NYMEX Henry Hub January contract settled yesterday at $3.54/MMBtu, about 30.8 cents (~10%) above where the December contract expired ($3.232) and 77.6 cents (28%) higher than where November settled ($2.764). The natural gas winter withdrawal season is officially underway—it’s a lot colder and gas demand has spiked. But this week also marks another key bullish threshold: as today’s Energy Information Administration (EIA) storage report will likely show, the U.S. natural gas inventory has fallen below the prior year’s levels for the first time in two years (since early December 2014). That’s in sharp contrast to where the inventory started the injection season in April—more than 1,000 Bcf higher compared to April 2015. Moreover, we expect the emerging deficit to grow substantially over the next several weeks. Today we look at the supply-demand fundamentals driving this shift and what it means for the winter gas market.
The U.S. natural gas market in the past two years has undergone massive change, from breaking storage records and crossing long-held thresholds to flipping flow patterns and pricing relationships on their heads. This November, the market crossed yet another milestone: the U.S. became a net exporter of natural gas for the first time ever on September 1, 2016. That lasted only a few days. But net exports resumed again starting November 1 and have continued through the month, almost without interruption, with pipeline deliveries to Mexico and to the first two liquefaction “trains” at Cheniere Energy’s Sabine Pass LNG terminal exceeding imports from Canada and LNG import terminals by an average 0.6 Bcf/d. Today, we look into what’s really driving this shift and what that tells us about the trend going forward.
The increasing availability of LNG at low and relatively stable prices, combined with the ability to expedite the installation of LNG receiving/regasification infrastructure, has the potential to spur faster growth in global LNG demand than many have been expecting. If that happens, the current––and still growing––glut in worldwide liquefaction capacity could shrink in a few years’ time, and a “second wave” of U.S. liquefaction/LNG projects could start coming online by the mid-2020s. Today, we conclude our series on U.S. LNG exports with a look at how low, stable LNG prices may turn the market toward supply/demand balance.
After about four weeks offline for modifications and maintenance, Cheniere’s Sabine Pass liquefaction terminal in Cameron Parish, Louisiana began accepting nominal deliveries of feed gas starting last Friday, indicating the facility is due to ramp up to capacity any day now. Since the first export cargo in February, about 130 Bcf, or 0.6 Bcf/d, of natural gas has been delivered to the terminal. While those aren’t quite game-changing volumes yet, deliveries just prior to the outage were averaging more in the vicinity of 1.2 Bcf/d and indications are that deliveries could ramp up to more than 1.0 Bcf/d in short order with the restart and grow to more than 2.0 Bcf/d by the end of 2017. It’s clear that LNG exports are quickly becoming a prominent and inescapable feature of the U.S. natural gas market. Today, we wrap up our series on the growing impact of LNG exports on the U.S. supply/demand balance.
Developing a multibillion-dollar liquefaction/LNG export project takes perseverance and patience––and having good luck wouldn’t hurt. The “first wave” of U.S. projects is now cresting; the first two liquefaction “trains” at Cheniere Energy’s Sabine Pass LNG facility are essentially complete, and 12 other trains are under construction and scheduled to come online in the 2017-19 period. But what about the “second wave” of projects that was supposed to be arriving soon thereafter? Today we continue our series on the next round of U.S. LNG projects with a run-through of the projects themselves and a look at how (despite the current market gloom) there is at least some cause for optimism that a few may get built by the early 2020s.
The “first wave” of liquefaction/LNG export projects in the U.S. is cresting. Two new liquefaction trains in Louisiana are already producing liquefied natural gas, and a dozen other trains are under construction and scheduled to begin commercial operation in the Lower 48 over the next three years. The problem is, these multibillion-dollar facilities––planned when LNG market dynamics were much more favorable––are “rolling in” as the global market faces a supply glut, weak LNG demand growth, and low prices. Today, we begin a series on the next round of U.S. LNG projects and how soon market conditions might improve enough to justify building them.
It’s been a volatile summer for U.S. natural gas. The CME NYMEX front month contract spiked from $1.96/MMBtu in late May to $2.99 on July 1, up more than 50% in just over a month. Since then the price has headed mostly south, closing at $2.62/MMBtu on Tuesday, down $.37/MMBtu from its summer high a few weeks ago. As often is the case, the primary culprit has been weather. But for the first time, a new factor is starting to have an impact: LNG exports. During August, approximately 30 Bcf of gas will likely flow into Cheniere Energy’s Sabine Pass for now-routine LNG exports from Train 1 and the initial volumes needed for the start-up of Train 2. The more recent decline in gas prices just happened to follow the announcement that the entire Sabine Pass LNG facility will be shut down for several weeks starting next month for maintenance and to address a design issue. Was LNG a factor in the price decline? Hard to say. We may get a better sense of the market impact of LNG exports when the plant starts back up. At that point even more gas –– up to 1.25-1.5 Bcf/d in total –– could be sucked out of the market, possibly taking a 125-Bcf bite out of supply by the end of this year. The gas market has changed. From here on out, you won’t be able to understand the U.S. natural gas market without a solid grasp of LNG export dynamics. Today, we begin a two-part series on how international demand for U.S.-sourced LNG will have an increasing effect on gas supply, demand and price.
Since the first LNG ship left its dock in February, Cheniere’s Sabine Pass LNG terminal has exported 17 cargoes containing the super-cooled, liquefied equivalent of over 50 Bcf of natural gas from the first of six planned liquefaction “trains.” And in a monthly progress report filed with the Federal Energy Regulatory Commission last month, Sabine Pass said it expected to begin loading a commissioning cargo from Train 2 in August, with commercial operation of that facility starting as early as September. In today’s blog we provide an update of Sabine Pass’s export activity, as well as the impact on the U.S. gas flows and demand.
The international market for liquefied natural gas (LNG) is in the midst of a wrenching transition. The old order, founded largely on long-term, oil-indexed contracts that called for certain volumes of LNG to be delivered by specified Point A to specified Point B, is being replaced by a new order characterized by intense competition among suppliers, new sources of supply (and demand), a glut of liquefaction capacity expected to last at least a few years, more spot purchases, and contracts incorporating destination flexibility—and, for many, tied to natural gas (not oil) prices. Today, we continue our exploration of the industry’s fast-changing dynamics with a look at the fierce battle now under way among LNG suppliers for market share, and at new approaches to pricing LNG.
There’s too much new liquefaction capacity coming online worldwide, too little growth in liquefied natural gas (LNG) demand, and it’s probably too late to prevent a multiyear period of LNG supply glut and low LNG prices. That’s not welcome news to those who have committed to long-term, take-or-pay deals with the new liquefaction “trains” set to come online in the U.S. and Australia in 2016-20, but it’s the reality. What’s making things worse yet is that new entrants in the LNG market are facing push-back from entrenched LNG and natural gas suppliers (Qatar, Russia and Norway) eager to retain market share (much like Saudi Arabia’s been doing in the crude oil market). There’s cause for longer-term optimism, though. Today, we begin an update on the international gas market.
As if the international market for liquefied natural gas weren’t complicated enough, add the facts that 1) the LNG shipped from various export terminals differs in chemical composition, and 2) the specifications for the natural gas consumed by various countries around the world differ too. In other words, you can’t assume that the heating value and other important characteristics of the super-cooled gas in the LNG shipped from exporting country A will align with the gas specs enforced in importing country B. That’s a big deal to LNG exporters and traders who would like to be able to ship their LNG to wherever it would make the most money, but who need to consider a lot more. Today, we look into the increasing significance of LNG/gas spec differences as the old rules of the LNG market break down.
Lately, it’s not just liquefied natural gas (LNG) prices that are headed south, it’s LNG cargoes too. A few days ago, the first LNG shipment from Cheniere Energy’s Sabine Pass liquefaction/export terminal was sent to Brazil, where a drought has slashed hydroelectric production and boosted the need for natural gas-fired power.
After years of debate and speculation regarding prospects for U.S. exports of liquefied natural gas (LNG), the first cargo left the Gulf Coast around 8:30 pm EST Wednesday (February 24, 2016) from Cheniere’s Sabine Pass terminal, according to Genscape’s global LNG cargo monitoring service. The vessel carrying a little more than 3.0 Bcf of LNG is reportedly bound for Petrobras in Brazil. The incremental export demand that this LNG cargo and others like it to follow represent, is potentially good news for U.S. gas producers, with benchmark futures prices at Henry Hub, LA closing yesterday (February 25, 2016) near record seasonal lows at $1.711/MMBtu in the face of mild winter demand, record production and brimming storage levels. Today we look at how this first cargo was supplied and what that tells us about current and future impact to flows and regional prices.