RBN Energy Blogcast RBN Energy

There’s never been any reason to question the drivers for energy infrastructure development — until now.  Historically, the drivers were almost always “supply-push.” The Shale Revolution brought on increasing production volumes that needed to be moved to market, and midstreamers — backed by producer commitments — responded with the infrastructure to make it happen. But now things seem to be different. U.S. energy infrastructure investment is soaring across crude oil, natural gas and NGL markets and, as in previous buildouts, midstreamers are bringing on new processing plants, pipelines, fractionators, storage facilities, export terminals and everything in between. We count nearly 70 projects in the works. But crude production has been flat as a pancake, natural gas is down, and lately NGLs are up — but as you might expect, only in one basin: the Permian. So what is driving all the infrastructure development this time around? In today’s RBN blog, we’ll explore why that question will be front-and-center at our upcoming School of Energy: Catch a Wave. Fair warning, this blog includes an unabashed advertorial for our 2024 conference coming up on June 26-27 in Houston. 

Rome wasn’t built in a day and neither were the large, wellhead-to-market natural gas and NGL networks that Phillips 66 and a handful of other midstream empires have assembled — many of them targeting the all-important Permian. Now, P66 has reached an agreement to acquire Pinnacle Midstream, whose associated gas gathering system and gas processing complex in the heart of the Midland Basin nicely complement a host of other gathering and processing assets P66 controls through its majority stake in DCP Midstream. In today’s RBN blog, we’ll discuss P66’s planned purchase of Pinnacle Midstream and what it means for the Permian piece of the acquiring company’s broader natgas/NGL system. 

The Houston crude oil hub has become busier over the last few months, and if one or more proposals to build a deepwater export terminal nearby capable of fully loading a Very Large Crude Carrier (VLCC) cross the finish line, it could become the hub supplying them. That could push Permian Basin oil flows on Houston-bound pipelines higher at the expense of flows to Nederland and Corpus Christi. In today’s RBN blog, the third in a series, we will examine the latest Permian oil flows to Houston and how that could change if and when a deepwater project comes online. 

There’s never been any reason to question the drivers for energy infrastructure development — until now.  Historically, the drivers were almost always “supply-push.” The Shale Revolution brought on increasing production volumes that needed to be moved to market, and midstreamers — backed by producer commitments — responded with the infrastructure to make it happen. But now things seem to be different. U.S. energy infrastructure investment is soaring across crude oil, natural gas and NGL markets and, as in previous buildouts, midstreamers are bringing on new processing plants, pipelines, fractionators, storage facilities, export terminals and everything in between. We count nearly 70 projects in the works. But crude production has been flat as a pancake, natural gas is down, and lately NGLs are up — but as you might expect, only in one basin: the Permian. So what is driving all the infrastructure development this time around? In today’s RBN blog, we’ll explore why that question will be front-and-center at our upcoming School of Energy: Catch a Wave. Fair warning, this blog includes an unabashed advertorial for our 2024 conference coming up on June 26-27 in Houston. 

Energy Transfer, which is championing its Blue Marlin Offshore Platform (BMOP), may have been the last developer to pursue its critical deepwater export license, but that doesn’t mean it’s out of the hunt. Of the four offshore crude oil export projects, BMOP stands out as the sole brownfield initiative, which should hold down costs and expedite its construction timeline. Further, a recent non-binding agreement with TotalEnergies underscores the industry’s interest in this unusual but compelling facility. In today’s RBN blog, we explore Energy Transfer’s unconventional approach. 

Permian production may have plateaued over the past few months — the shale play’s crude oil output has bounced between 6 MMb/d and 6.3 MMb/d for almost a year now, and natural gas production has hovered around 18 Bcf/d for about as long. But producer-backed plans to continue adding gas processing capacity in the Permian’s Delaware and Midland basins strongly suggest that E&Ps in West Texas and southeastern New Mexico see a lot more production growth “up around the bend.” As we discuss in today’s RBN blog, midstream companies haven’t tapped the brakes on their plans for new gas processing capacity in the Permian — in fact, they’ve been keeping the pedal to the metal.