In the Energy Information Administration’s (EIA) latest ethane production stats — for the month of May — gas plant production of ethane exceeded 1.4 MMb/d for the first time. In the same month, ethane exports also hit a record at 191 Mb/d, and ethane demand for petrochemical production — you guessed it — hit still another all-time high, topping 1.2 MMb/d. All this is just the beginning. These numbers and the throughput of any midstream infrastructure transporting or fractionating ethane will continue to increase over the next two years as new, ethane-only crackers come online, ethane rejection dwindles and overseas exports of ethane ramp up. By 2020, U.S. ethane demand is expected to reach 2 MMb/d — up by two-thirds from where it stands now. Today we continue our series on rising ethane demand, how the new demand will be met and what it all means for ethane prices.
MPLX is wrapping up a three-part, $500 million plan to facilitate the pipeline transport of large volumes of field condensate and natural gasoline from the Marcellus and Utica plays to Midwest refineries, western Canadian heavy-crude shippers and other end users. But “wrapping up” may be the wrong phrase. In fact, MPLX sees its Cornerstone Pipeline, Utica Build-Out Projects and other elements of the company’s Midwest pipeline push as part of a larger and continuing effort to deal with remaining inefficiencies in the delivery of Marcellus/Utica liquids to market. Today we review what has been accomplished so far, and what expansions and enhancements to MPLX’s pipeline plan may be in the offing.
The last couple of years have been a wild ride for the U.S. ethane market, but look out ahead. It’s going to get crazy. The onslaught of new, ethane-only crackers is upon us at the same time overseas exports are expected to ramp up. At first glance, it might appear there is enough ethane to meet all that demand, coming from molecules that today are being rejected — that is, sold as natural gas rather than liquid ethane. But the big question — will it be enough? Because not all that rejected ethane has access to pipeline capacity needed to get it to market, at least not right now. In today's blog, we begin a new series on rising ethane demand, how the new demand will be met, and what it all means for ethane prices.
For the first time in six years, pipeline flow data show that natural gas production from Louisiana’s Haynesville Shale is rising. Additionally, rig counts and producers’ plans suggest more growth is on the way. Is the play poised to create a whole new crop of Bayou Billionaires? Or is this a head fake that will only make us long for days of Haynesville past. Well, it depends. Because even though the Haynesville basin is looking up, it still faces some formidable challenges, from its geology to competition from other supply regions. Today, we continue our look at Haynesville’s prospects.
For much of the past few years, natural gas at Northeast demand market hubs has been priced at deep discounts, particularly in the low-demand summer months, because of the flood of Marcellus Shale gas that couldn’t go anywhere else. But now, those markets could soon see some upward pressure as pipeline projects that will expand takeaway capacity from the region come online. One of those projects is Williams’s Transco Pipeline Dalton Expansion, which includes an expansion of Transco’s mainline as well as a new, “greenfield” lateral. The project has already commenced partial-path service to move as much as 448 MMcf/d south on the mainline from Transco’s Zone 6 in New Jersey to its Zone 4 segment in Mississippi. And just yesterday (Thursday, July 13), Transco submitted a request with the Federal Energy Regulatory Commission (FERC) to place the remaining portion — the new Dalton Lateral pipeline extension and related connections — into service less than three weeks from now (on August 1). Today, we provide an update on the project and potential market effects.
After years of oversupply conditions and pipeline constraints, the U.S. Northeast natural gas market is on the verge of reaching a point where it is unconstrained by transportation capacity and enjoys increased optionality for reaching growing demand markets downstream. There are no fewer than 20 pipeline projects in the works to facilitate that. If all – or even most of them get built, the region would develop the opposite problem — not enough gas to fill all that new pipe. Ultimately, the state of the Northeast market will come down to the timing of the expansions projects compared with the pace of production growth. Today, we conclude this series with a look at how supply will line up with pipeline expansion in-service dates over the next five years.
For years now, U.S. Northeast natural gas production growth has been paced by the availability of pipeline takeaway capacity out of the Marcellus/Utica shales. Midstream companies have been racing to build the infrastructure to support drilling and rising supply in the region. And, until now, it was safe to assume that as new pipeline projects come online, volumes would grow to fill them in short order. But over the next couple of years, that may flip: takeaway capacity additions could soon outpace supply increases, and producers might not be able to keep up. Today, we provide an update of RBN’s Northeast gas production scenarios.
A record amount of natural gas supply — close to 8.0 Bcf/d — from the Marcellus and Utica shale plays is making its way to the broader U.S. market. That’s happened with the help of a substantial build-out of pipeline infrastructure to reverse gas flows out of the now oversupplied Northeast, which has allowed regional production to grow to nearly 23 Bcf/d from less than 8 Bcf/d five years ago. One of the major target markets for this gas has been the Midwest. About a third of current outbound flows is heading to the Midwest, primarily via the reversal and expansion of Tallgrass Energy’s Rockies Express Pipeline, completed earlier this year. Moreover, midstream companies are due to install an additional 5.5 Bcf/d or so of takeaway capacity to target the Midwest and Canada by late 2020, with 70% of that due this year alone, starting with Energy Transfer’s Rover Pipeline. However, many of these expansion projects have been embattled by regulatory, environmental and political hurdles during the approval process. Today we provide an update of Rover and other Midwest- and Canada-bound takeaway projects.
Plans for LNG export terminals, petrochemical plants and gas-fired power generation along the Gulf Coast have made it the #1 target market for Marcellus/Utica natural gas producers. At the same time, these demand projects along the coast, from the Southeast, Texas and even farther down in Mexico, are counting on more supply growth from Appalachia. Since 2014, close to 5.0 Bcf/d of southbound pipeline capacity has been added and another 4.0 Bcf/d is due by early 2019. Today, we continue our update of pipeline expansions out of Appalachia, this time with a focus on the Ohio-to-Gulf Coast corridor.
One of the major target markets for Appalachian natural gas is the U.S. Southeast. More than 32 GW of gas-fired power generation units are planned to be added in the South-Atlantic states by 2020 and LNG exports from the Southeast are increasing. Of the 15.5 Bcf/d of takeaway capacity planned for Appalachia, close to 5 Bcf/d is targeting this growing demand. Despite the need, these pipeline projects designed to increase southbound flows from the Marcellus Shale have faced regulatory delays and setbacks. Today, we provide an update on capacity additions moving gas south along the Atlantic Coast.
Since 2013, nearly 3.0 Bcf/d of natural gas pipeline capacity has been added from Appalachia to the heavily populated, hard-to-reach demand centers along the East Coast. And another nearly 3.0 Bcf/d is in the works. The need for gas supply reliability in the heavily populated East, along with producers’ need to move their gas to market, is driving these expansions. But concentrated population centers, along with the geography, geology and regulatory environment of the area, all also make it tough and expensive for upgrading, expanding and developing the gas transportation system. Many of the proposed projects have been delayed or canceled as a result. Today, we provide an update on eastbound pipeline expansions from Appalachia.
For years now, limited natural gas pipeline takeaway capacity has constrained gas production growth in the Marcellus/Utica natural gas shale plays in the Northeast. To fix that, a slew of pipeline projects were planned to relieve the constraints as regional supply began outstripping demand starting in 2014. Now, the region is on the verge of being unconstrained for the first time since the Shale Revolution hit Appalachia. Many of those projects have come online since then, and another 19 expansions totaling 15.5 Bcf/d are planned for completion by late 2019. If all goes as expected, this next round of projects should turn the Northeast market on its head again, as the capacity additions should start to outpace production growth. The problem, though, is that several projects have faced significant challenges in recent months, resulting in either cancellation or major delays. At the same time, Marcellus/Utica production growth has slowed dramatically in the past 18 months or so. In today’s blog, “In a Northeast Minute…Everything Can Change — An Update of Marcellus/Utica Takeaway Projects,” Sheetal Nasta begins a series looking at the status of regional takeaway capacity expansions.
Natural gas production growth in the U.S. Northeast—the primary driver of U.S. production growth in recent years—has slowed dramatically in the past few months, up no more than 1 Bcf/d year-on-year, compared with growth in increments of 3 and 4 Bcf/d in previous years. Despite the slowdown, the regional balance continues to lengthen, with supply growth outpacing demand. Yet, regional gas prices, specifically at key supply hubs, which previously were struggling under the weight of oversupply coupled with limited access to growing demand markets, are strengthening. Is this the beginning of the end of takeaway constraints and distressed supply pricing in the region? Or will constraints reemerge this summer? Today, we provide an update of Northeast gas supply/demand balance.
As a group, the nine natural gas-focused exploration and production companies that were analyzed in our Piranha! market study are forecasting a 62% increase in capital spending in 2017 compared with 2016, a significantly higher percentage gain than their oil-focused and diversified counterparts. The driver of accelerated investment is the expected completion of natural gas infrastructure that will boost takeaway capacity from the Marcellus and Utica shales, the operational focus of eight of the nine gas-weighted E&Ps. Expanded access to Canadian, Midwestern, Gulf Coast and export markets should significantly boost realizations and margin. Production growth by the nine E&Ps, which slowed to 4% in 2016 after a 19% rise in 2015, is expected to accelerate to 10% in 2017 and to rise rapidly in 2018 and beyond. Today we continue our analysis of U.S. E&P capital spending and production trends by taking a deep dive into the investment strategies of the natural gas-weighted peer group.
Rising natural gas exports from South Texas and increasing production of “associated” gas in the Permian Basin are driving the development of several new gas pipelines from West Texas to the Agua Dulce gas hub and nearby Corpus Christi. The age-old questions apply: How much new pipeline capacity will be needed, and how soon? The construction of these new pipelines also raises the question of how a potential flood of new gas supply from the Permian to the South Texas coast might affect plans by others to flow gas down the coast from Houston. Today we continue our look at proposed gas pipelines from the Permian to Agua Dulce and Corpus Christi with a review of two more projects and their potential impact.