RBN Energy Blogcast

Which is true, A or B? (A) Data center demand to power AI applications is the most transformative force to hit energy markets in years, or (B) This is one of the most overhyped, inflated narratives ever. We hear a constant stream of announcements, promotions and proclamations from developers, tech giants, utilities and politicians, many predicting a revolutionary surge in electricity and gas demand that will change everything. At the same time, others warn of a speculative bubble destined to pop. As we discuss in today’s RBN blog, sorting out which side is closer to reality is one of the most important questions facing U.S. energy markets. 

For most of us, matching spending with income is the logical path to financial stability. However, after decades of aggressive investment in search of growth, the “dollars in equals dollars out” method of allocating free cash flow has been an adjustment for many U.S. oil and gas producers. Their post-pandemic concentration on keeping capital spending well below inflows, maintaining healthy leverage ratios and directing excess funds to reward shareholders with dividends and stock buybacks has revitalized the industry and restored investor confidence. But ebbing commodity prices have upped the difficulty of this quarterly zero-sum game. In today’s RBN blog, we will analyze the shifts detected in Q2 2025 cash allocation of the 38 major U.S. E&Ps we cover. 

After a decade of regulatory and legal challenges, Mountain Valley Pipeline (MVP) finally came into service in the middle of last year. The 2-Bcf/d pipeline — soon to be expanded to 2.5 Bcf/d via additional compression — was designed to ease natural gas takeaway constraints out of the Marcellus/Utica and help production there break past its current plateau near 36 Bcf/d, but bottlenecks on the massive Transco Pipeline have complicated matters. In today’s RBN blog, we look at efforts to unleash more Appalachian gas in the domestic market, focusing on the Southside Reliability Enhancement Project (SREP), which has enabled more gas to reach North Carolina. 

Refineries in Europe, Latin America, Russia and China are facing a host of issues that could ultimately benefit U.S. refiners. Europe has high operating costs and political pressures. Attacks have damaged Russia’s refineries, and the country continues to get blasted with steeper sanctions. China’s aging plants are closing and there are no new large-scale projects on the horizon. Latin America lags in capacity growth. In today’s RBN blog, we look at how these global issues are boosting opportunities for U.S. refiners. 

U.S. interstates are populated with electronic displays that update drivers in real-time on traffic conditions, road closures, weather alerts and other important events. If there was a sign for executives steering our nation’s oil and gas producers, it would likely read “Poor Visibility, Slow Down Ahead.” After a short-lived price rally in Q1 2025, the industry faced lower commodity realizations and macroeconomic headwinds in Q2 2025, which spooked investors and hardened a cautious investment approach. In today’s RBN blog, we analyze the latest results of the 39 major U.S. E&P companies we cover and look at what’s ahead. 

The fact is, many major E&P acquisitions include at least some production assets that don’t align with the acquiring company’s long-term strategic plans. Also, it’s often true that big-dollar M&A increases the buyer’s debt level — and it’s typical in such cases that the company commits to quickly reducing its debt through the divestiture of non-core assets. As we discuss in today’s RBN blog, there’s a lot of that going on now, and in many cases smaller, private-equity-backed producers are scooping up the acreage and production being sold. 

Midstreamers developing natural gas takeaway capacity out of the Permian have understandably focused on pipelines to the Gulf Coast — and along the coast to LNG export terminals and other big gas consumers. But don’t forget the Desert Southwest, where demand for gas-fired power is soaring. Energy Transfer recently committed to building a 516-mile, 1.5-Bcf/d expansion to its Transwestern Pipeline system from West Texas to the Phoenix area, and hinted that it might double the project’s capacity due to the high level of interest. In today’s RBN blog, we discuss Energy Transfer’s aptly named Desert Southwest Project, what drove its quick progress to a final investment decision (FID), and what other westbound projects out of the Permian might still happen. 

In the U.S., crude oil trading hubs like Houston, Midland and Cushing get the lion’s share of the market’s attention. But travel a bit further north and you can find one of the more unusual and liquid crude markets in the country — Guernsey, WY — a focal point for producers in Western Canada, North Dakota, Wyoming, Utah and Colorado. Over the last few months, Guernsey differentials have tightened significantly, finally flipping to a premium to Cushing. We have seen this phenomenon occur before, most notably seven years ago after the startup of the Dakota Access Pipeline (DAPL). In today’s RBN blog, we discuss the recent movement in Guernsey differentials and what the future could hold for the often-overlooked sales point. 

As demand for data centers accelerates, developers continue to search for locations that offer the best combination of several factors, starting with the availability of uninterrupted (and affordable) power. Those variables have led to a data-center buildout in several parts of the U.S., such as Northern Virginia, Texas and California’s Silicon Valley, but Canada has its own set of positives to lure developers. In today’s RBN blog, we look at the state of data-center development in Canada, how the factors that affect site selection differ from the U.S., and how Canada is working to become a bigger player in the global market. 

The original Cactus Pipeline was a pioneer in moving large volumes of crude oil from the Permian and the Eagle Ford to the Corpus Christi area, which quickly became a leader in U.S. crude exports. Cactus II, an even longer and larger pipeline that came online in H2 2019, only added to Corpus Christi’s export prominence. But the competition with Permian-to-Houston pipelines is fiercer than ever and negotiated rates on pipelines to the Texas Gulf Coast are under pressure. In today’s RBN blog, we look at the Cactus I and Cactus II pipelines and their significance. 

A crude oil leak last Tuesday at the Enterprise Crude Houston (ECHO) terminal disrupted regional flows and caused crude differentials to move higher over the course of the week. While the spill was swiftly addressed by terminal owner Enterprise Products Partners, it still affected inbound and outbound operations for a few days. In today’s RBN blog, we discuss the role of the ECHO terminal and show how even an isolated incident can quickly have an impact on the market. 

A few months ago, Enbridge unveiled its plans to expand its massive Mainline and smaller Express/Platte crude oil pipeline systems into the U.S. Midwest/Great Plains. We blogged about those plans, and followed up with a look at how the incremental volumes of Western Canadian crude on the Mainline and Express/Platte might move south from PADD 2 to where they’re wanted most: the Gulf Coast. In today’s RBN blog, we discuss efforts to piece together a more direct pipeline route from Alberta to Cushing and on to the Texas/Louisiana coast. 

The build-out of the Permian’s midstream infrastructure over the past 10 years has created extraordinary opportunities for startup companies, most of them backed by private equity. Each of us could cite several examples of midstreamers that, with a combination of guile and grit, developed gathering systems, gas processing plants, pipelines and other infrastructure to serve the fast-growing needs of producers and shippers. In many cases, the assets they constructed were later sold — often at a hefty profit — to much larger firms. As we discuss in today’s RBN blog, even in the midst of sector consolidation, the entrepreneurial spirit of smaller Permian midstreamers continues. 

Odds are there’s never been a busier, more frantic time for natural-gas-related infrastructure development in Texas and Louisiana than right now. Construction is underway or imminent at no fewer than seven Gulf Coast LNG export terminals with a combined capacity of 16 Bcf/d.

The U.S. refining industry has undergone a number of changes in recent years and more turbulence looks likely as global economic and trade patterns shift and energy transition moves forward. For some refineries, this has led to closures due to weak profits, rising regulatory costs and declining demand for products, particularly gasoline. But other refineries have prospered — and even invested in expansions — while the U.S. industry as a whole has evolved into the most competitive system in the world. Overall, the prospects have been very regionally (and even facility) specific. As detailed in the most recent Future of Fuels report from our Refined Fuels Analytics (RFA) practice, this regional differentiation will continue and shift over the coming years. In today’s RBN blog, we’ll discuss what we expect for the U.S. refining industry — where closures will likely take place, where the industry might actually add capacity, and the reasons for those actions. 

Data centers are a buzzy topic in the energy industry, and while there is still a lot of fuzziness about what will actually get built and how much natural-gas-fired power will be needed to support these projects, there’s no doubt that major technology companies are well along in planning a number of massive data centers across the country. In today’s RBN blog, we’ll offer a snapshot of the plans announced by tech giants Microsoft, Amazon, Alphabet (Google) and Meta (Facebook). 

The oil and gas industry is always working to develop the most efficient methods for unlocking more hydrocarbons. To cut costs and maximize output from their acreage, some companies are rolling out more creative well designs, such as U-turn (aka “horseshoe”) and J-hook wells, which use dramatic, 180-degree underground turns to access more oil and gas from each location. In today’s RBN blog, we’ll discuss the benefits of these approaches and the technical hurdles associated with drilling these deep bends underground. 

Any number of things can impact the price of specific types of crude oil at various locations — supply interruptions, takeaway constraints and refinery outages, to name just a few. Every so often, the stars align and just about all those factors narrow the differential between, say, Western Canadian Select (WCS) and West Texas Intermediate (WTI) at the U.S. Gulf Coast to near-record levels. Well, that’s happening now, for the first time in five years. In today’s RBN blog, we discuss the shockingly small WCS/WTI differential and what’s driving it. 

The European Union (EU) appears poised to substantially increase its imports of U.S. LNG after reaching a trade deal with the Trump administration that includes a pledge to purchase $750 billion worth of U.S. energy over three years. The trade agreement and the EU’s plans to phase out deliveries of Russian LNG and piped-in natural gas by 2027 may end up being a big positive for U.S. producers. But that doesn’t mean it’s all clear sailing, thanks to competition with Qatar and uncertainty around EU regulations. In today’s RBN blog, we look at how U.S. exporters could still get squeezed on price and volume between today and 2030. 

Not long ago, several large-scale carbon-capture projects had plenty of momentum, fueled by a push toward decarbonization and expanded federal tax credits. But while progress on many projects has slowed as they faced a host of problems, Tallgrass’s plan to convert its Trailblazer pipeline from natural gas service to carbon dioxide (CO2) has had a comparatively smooth ride, thanks in large part to an engagement strategy that has allowed it to navigate the trickiest potential complication — local opposition. In today’s RBN blog, we review Trailblazer’s conversion, examine why Tallgrass’s strategy has succeeded where similar projects have failed, and look at what happens next. 

The San Juan Basin in northwestern New Mexico and southwestern Colorado has seen more than its share of booms and busts in the last 100-plus years. During the Shale Era, natural gas production in the 7,500-square-mile basin has been slowly declining, undercut by competition from more prolific, better-situated wells in the Permian and Eagle Ford. But a small band of “San Juan believers” think the region is poised for yet another rebound, this time due to what they view as massive, untapped potential in the basin’s Mancos Shale. In today’s RBN blog, we discuss recent developments in the San Juan — and the basin’s extensive pipeline infrastructure. 

Western Canadian crude oil production is rising fast. To keep pace, Enbridge is planning expansions to its pipelines into the Midwest and Great Plains. But PADD 2 refineries are maxed out on heavy crude, so virtually all those incremental barrels will need to keep flowing south to refineries and export terminals along the Gulf Coast. Can the pipelines from PADD 2 to PADD 3 handle the higher volumes? In today’s RBN blog, we discuss the knock-on effects of rising Western Canadian production and Enbridge’s pipeline expansions. 

MPLX’s July 31 announcement that it has reached an agreement to acquire Northwind Midstream for $2.375 billion puts a spotlight on two undeniable trends. First, the acquisition is the latest in what by now is a long series of multibillion-dollar deals by midstream giants to expand their Permian-to-Gulf, “wellhead-to-water” networks that gather, process, transport and export crude oil, natural gas and/or NGLs. Second, Northwind has been a pioneer in gathering and processing unusually sour associated gas in the prolific Northern Delaware Basin, an area of particular interest to a growing number of E&Ps. In today’s RBN blog, we discuss the deal and what it brings to MPLX. 

U.S. E&Ps’ strategic shift from growth at any cost to a laser focus on cash flows to fund shareholder returns revitalized their investor base. But that strategy has been challenged as crude oil prices have eroded since their mid-2022 peak, with producers struggling to balance the need to maintain output and the pressure to sustain dividends. In today’s RBN blog, we’ll see how things are going with the oil and gas companies that bear no responsibility for the costs and complications associated with the finding, development and production of hydrocarbons — the entities that own mineral and royalty interests. 

Crude oil producers in the prolific Permian Basin have plenty of options to move their barrels, especially since pipeline capacity currently exceeds production, but not every route out of the basin is equal. One of the hottest destinations for Permian crude is Houston, which boasts an attractive mix of refining and export demand. In today’s RBN blog, we look at the pipelines that transport Permian crude to Houston, discuss why it’s such a vital spot, and preview our latest Drill Down Report. 

Through the early years of the Shale Era, produced water gathering systems in the Permian were mostly small, simple and focused solely on transporting the salty, petroleum- and mineral-tainted water emerging from wells to nearby saltwater disposal wells. In the 2020s, though, these systems — now mostly owned and operated by third-party produced water specialists — have been becoming larger, more interconnected, and more likely to include at least some water recycling and reuse. In today’s RBN blog, we’ll continue our look at big, far-reaching produced water systems in West Texas and southeastern New Mexico. 

It's an integrated energy market that stretches across the North American continent, from Texas and Florida to the mountains of British Columbia and Canada’s industrial heartland in Ontario/Quebec — a cross-border network so deeply connected, it functions as one massive, interdependent system for oil, natural gas and NGLs. That system is undergoing major shifts and challenges, driven not only by changing supply/demand dynamics and evolving infrastructure within the market itself, but also by powerful external forces, including regulatory policies and political pressures. That’s why we couldn’t think of a better time — or a better place — to host RBN’s 19th School of Energy than in Calgary next month. In today’s RBN blog — a blatant advertorial — we’ll highlight how our upcoming conference will dig into how the interconnected energy landscape is changing and why understanding those shifts is more critical than ever. You Ain’t Seen Nothin’ Yet! 

Expectations for electric vehicle (EV) adoption in the U.S. took a sharp detour into uncharted territory earlier this month when President Trump signed the landmark budget reconciliation bill into law. Known as the One Big Beautiful Bill Act (OBBBA), the law dramatically scales back EV subsidies, eliminates penalties for automakers that don’t meet fuel-efficiency standards, and significantly restricts state-level zero-emission vehicle (ZEV) programs. In today’s RBN blog, we look at why the law is likely to slow the pace of EV adoption and impact forecasts for vehicle sales and gasoline demand — a key topic in the just-published Future of Fuels report from our Refined Fuels Analytics (RFA) practice.

Perhaps the most hyped-up topic in energy these days is how much electricity new data centers will need to keep up with the increased use of artificial intelligence (AI). And that’s prompting some big questions, such as where all the power will come from and how much natural gas demand will rise. But another crucial question may be whether these data centers will pull that power from the grid or generate it themselves on-site. In today’s RBN blog, we’ll discuss the benefits and challenges of each approach.

The Bakken Shale needs more natural gas takeaway capacity, North Dakota wants to encourage more in-state consumption of Bakken-sourced gas, and two entities — WBI Energy and a combo of Intensity Infrastructure Partners and Rainbow Energy Center — have each proposed similar (but not identical) cross-state pipelines that would help achieve those aims. But, assuming that two new pipelines would be overkill, which of the two proposals is the more likely to advance to a final investment decision (FID), construction and operation? In today’s RBN blog, we discuss the two competitors and the state of North Dakota’s impending decision on which pipeline project to support.

There’s a lot going on in the Permian produced water space lately. Crude-oil-focused production in the prolific shale play is generating vast and increasing volumes of produced water that needs to be recycled or injected into disposal wells. State regulators, concerned about injection-related seismic activity, are tightening their rules, ramping up oversight and cracking down. Produced water gathering systems are being expanded and long-distance pipelines are being planned and built. In today’s RBN blog, we discuss the latest developments and where things are heading.

Associated gas production in the Bakken Shale continues to increase and, with more NGL pipeline capacity coming online and a new option on the horizon, there’s a gunfight brewing between two of the U.S.’s largest midstreamers. At one end of a dusty Wild West street stands the sheriff in town, ONEOK, which recently completed an expansion of its Elk Creek NGL Pipeline. At the other is a renowned midstreamer from Texas, Kinder Morgan, which is staking a claim in the Rockies by converting its Double H crude oil pipeline to NGL service — renaming it Hiland Express when it does — and planning an NGL header pipeline. As we discuss in today’s RBN blog, Kinder is the first to challenge ONEOK in this space. 

The Rockies Express Pipeline (REX) has been transformative. Originally built as a west-to-east pipeline, its main job was to give Rockies natural gas a way to reach premium markets in the Midwest and the Northeast. But by the time it was constructed, surging production in the Marcellus and Utica shales had overwhelmed the need for Rockies gas in the East, and REX evolved to become a major outlet for Appalachian gas to the Midcontinent. Now, REX has moved beyond its first two incarnations, and its owner, Tallgrass Energy, has announced plans to build a greenfield pipeline that would connect REX and the markets it serves with the prolific Permian Basin, 900 miles south of the existing mainline. In today’s RBN blog, we’ll discuss REX’s history, where it stands today, and how a new pipeline connection with the Permian might fit into its evolving strategy. 

The budget reconciliation bill signed into law July 4 by President Trump — known as the One Big Beautiful Bill Act (OBBBA) — dramatically scales back a number of clean-energy tax credits and adds a new layer of complexity for some projects, leading to a lot of doom and gloom around clean-energy initiatives, but the new legislation is a big positive for the carbon-capture industry. In today’s RBN blog, we look at how changes to the 45Q tax credit could help advance carbon-capture efforts while also providing a boost to producers of crude oil and blue hydrogen. 

The bitter, eight-year battle to control CITGO Petroleum’s three U.S. refineries could soon be coming to an end. A Delaware court has recommended a $7.38 billion bid from Dalinar Energy Corp., the U.S. subsidiary of Canadian miner Gold Reserve Ltd. There’s opposition, but a final decision could be just weeks away. In today’s RBN blog, we’ll discuss what a resolution would mean for the three refineries, which have a combined capacity of more than 800 Mb/d. 

The European Union (EU) has taken a number of steps in recent years to end its reliance on Russian natural gas, which accounted for nearly half of the bloc’s supplies before the 2022 invasion of Ukraine. But while the changes happening in Europe might provide a boost for global LNG exporters, including projects in operation or under development in the U.S., the EU’s policy shifts have also introduced greater uncertainty around demand. In today’s RBN blog, we look at the increasing difficulty in predicting EU gas demand and what it means for U.S. exporters and the rest of the global LNG market. 

The uncertainty and angst spurred by the ongoing trade war doesn’t seem to have dampened foreign companies’ interest in acquiring upstream and midstream energy assets in the U.S. The recent rumor — still unconfirmed — that Mitsubishi Corp. is in talks to acquire Aethon Energy Management’s massive holdings in the Haynesville for a reported $8 billion is only the latest indication that overseas interest may be stronger than ever. In today’s RBN blog, we’ll discuss the latest round of foreign investments in U.S. energy and what’s driving those deals. We’ll also look at the Aethon assets on the block. 

The Wink to Webster Pipeline, operated by ExxonMobil, stands out as the largest crude oil pipeline by capacity exiting the prolific Permian Basin in West Texas. What makes it even more of a midstream icon is the company’s hands-on management of the entire process, from the production well to the long-haul run to delivery to ExxonMobil’s refineries. In today’s RBN blog, we’ll examine Wink to Webster’s complicated ownership structure, how it connects directly to terminals run by its owners and its destination flexibility. 

Drilling techniques originally developed to unlock oil and gas from shale formations are increasingly being adapted to access and extract heat from deep underground rock formations, enabling the generation of electricity from geothermal sources. And while geothermal’s share of total U.S. electricity generation remains quite small, it may be poised to accelerate, opening up new opportunities for companies in the oil and gas sector. In today’s RBN blog, we explain the basics of geothermal energy, its main advantages and drawbacks, and how U.S. expertise in oil and gas comes into play. 

You might have thought the flurry of acquisitions and buyout deals that midstream companies entered into over the past couple of years would have satisfied their evident desire to refocus, expand and reshape their businesses. But you’d be wrong. In the first half of 2025 — a period of considerable uncertainty in the energy industry — midstream players continued to buy and sell pipelines and other important assets at a frenetic pace. In today’s RBN blog, we discuss some of the more interesting recent transactions and what they tell us about the midstream space. 

Alberta’s petrochemical industry received bad news in late April when Dow, one of the world’s largest petrochemical companies, announced that it was delaying construction on an immense expansion of its ethane cracker in Fort Saskatchewan, AB, only a little more than a year after sanctioning the project. Although the length of the delay remains uncertain, the slowdown has created unwanted ripples across other projects that were tied to the expansion, especially for companies working to provide a substantial increase in ethane and natural gas supplies that will be required by the project. In today’s RBN blog, we take a closer look at the delay and what it might mean for Alberta’s energy industry. 

The Marcellus/Utica has massive natural gas reserves, but daily, weekly and annual production in the three-state shale play is limited by three key factors: in-region demand, takeaway capacity and gas prices. In recent years, the basin’s output has been rangebound between 34 and 36 Bcf/d and Appalachian producers see only modest gains in 2025. But a handful of pipeline projects and rising gas demand from power generators suggest the Marcellus/Utica may finally be on the verge of a production breakout. In today’s RBN blog, we discuss the leading E&Ps’ production forecasts for 2025 and the prospects for considerably higher output by the end of this decade. 

It’s shaping up to be an incredible year for U.S. LNG growth, with record levels of feedgas demand and exports along with progress on the regulatory front, as the Trump administration has cleared away hurdles that had previously stalled project development. Now, Cheniere Energy has announced a positive final investment decision (FID) on its Corpus Christi Midscale expansion. In today’s RBN blog, we take a closer look at the Midscale project and others that could move forward this year. 

Canada’s energy industry has seen more than its share of merger-and-acquisition activity this year. The latest big deal involves the midstream sector, with Keyera agreeing on June 17 to buy Plains Midstream Canada’s NGL business in Canada for C$5.15 billion ($3.75 billion). The purchase will transform Alberta-focused Keyera into a nationwide NGL machine and caps its very busy first half of 2025. In today’s RBN blog, we take a closer look at the agreement and how it ties into other recent initiatives by the Canadian midstreamer. 

The Federal Energy Regulatory Commission (FERC) took several steps in June to slash red tape and speed the construction of natural gas projects in the U.S. interstate and export markets. This is the latest in state and federal efforts to reduce the years-long legal battles around energy infrastructure and quicken the development of vital projects such as pipelines and LNG terminals. In today’s RBN blog, we’ll highlight the recent efforts to remake and improve the permitting process. 

The details of a trade deal between the U.S. and China, announced June 26 by Commerce Secretary Howard Lutnick and confirmed by China, remain sparse. Once they are finalized, the requirement for U.S. exporters to obtain a Bureau of Industry and Security (BIS) license to send ethane to China should be lifted, but the effect on trade flows is already apparent. In today’s RBN blog, we review the impact of the BIS license requirement, the still-pending imposition of fees on vessels owned or operated by China, and the risk that comes with using the energy industry as a bargaining chip in trade talks. 

The Environmental Protection Agency’s (EPA) proposed Renewable Volume Obligations (RVOs) for 2026-27 did more than just set renewable fuel mandates for the next two years, they included dramatic shifts in the way that imported fuels and feedstocks are handled and raised the likelihood of higher compliance costs during a time in which the federal government has been focused on keeping prices under control. In today’s RBN blog, we look at the critical changes that will affect imported biofuels and feedstocks and the potential cost impact. 

Since its beginning in western Pennsylvania 166 years ago, the oil and gas industry has been on a relentless quest to unlock more hydrocarbons. And for years, the focus has been on drilling more productively, not just drilling more wells. The techniques that have evolved since the start of the Shale Revolution have led to rapid increases in the length of horizontal laterals, boosting initial production (IP) rates — a critical development but posing new challenges for drillers. In today’s RBN blog, we discuss why longer laterals in horizontal wells aren’t the answer in every shale play, the advantages of the two types of tubing used in those wells, and how they can help boost productivity. 

The summer movie season opened with the latest — and reportedly last — entry in the Tom Cruise-propelled “Mission: Impossible” franchise called “The Final Reckoning.” That title reminded us that, to E&P executives, the commodity price crash at the onset of the pandemic in 2020 must have seemed like the final blow in a series of financial crises that brought many of their companies to the verge of bankruptcy. But in a dramatic, “Mission: Impossible”-style recovery, producers restored their battered balance sheets and won back investors by radically shifting cash allocations. In today’s RBN blog, we’ll review the rise of the new E&P hero — dividends — and analyze how producers apportioned cash flows in Q1 2025. 

For several years now, the biggest hurdle to natural gas production growth in the Marcellus/Utica was takeaway constraints — there simply wasn’t enough capacity on gas pipelines out of Appalachia to support a significant bump-up in regional output. Things have been changing though. The Mountain Valley Pipeline and a slew of expansion projects along Transco are allowing increasing volumes of gas to move to and through Virginia and the Carolinas. The proposed Borealis Pipeline across Ohio would enable up to 2 Bcf/d to move down the Texas Gas Transmission system to the Gulf Coast. And, as we discuss in today’s RBN blog, Kinder Morgan is planning several major projects in the Deep South — including the 2.1-Bcf/d Mississippi Crossing and 1.3-Bcf/d South System Expansion 4 projects — to move more gas into Mississippi, Alabama, Georgia and South Carolina.