Crude oil production in the Denver-Julesburg (D-J) Basin has nearly doubled since January 2016 — only the Permian has outpaced the D-J’s growth rate over the same period — and production there now averages about 640 Mb/d. The D-J has just about everything producers want, including an unusually intense concentration of hydrocarbons within four geologic layers, or “benches,” only a few thousand feet below the surface, low per-well drilling costs, and direct pipeline access to the crude hub in Cushing, OK. Production growth in the D-J has spurred a rapid build-out of crude gathering systems and other infrastructure, especially in Colorado’s Weld County, the epicenter of D-J activity, which is located a short drive northeast of Denver. Today, we begin a series on existing and planned pipeline networks to move D-J crude from the lease to regional hubs and takeaway pipes.
Posts from Housley Carr
A number of proposed liquefaction plants and LNG export terminals along the U.S. Gulf Coast are racing to secure regulatory approvals and line up sales and purchase agreements, all in the hope of reaching final investment decisions before their rivals. Yet, these Texas and Louisiana projects now face competition from a facility that would be sited more than 3,000 miles away, in the icy waters just off the North Slope of Alaska. Qilak LNG would use a “near-shore” liquefaction plant in the Beaufort Sea off Point Thomson, AK, to supercool the region’s nearby, abundant and now largely stranded supplies of natural gas, load the resulting LNG onto ice-breaking carriers, and use these carriers to make shuttle runs to and from LNG customers in Asia. Today, we review the Qilak LNG project and the economic and logistic rationales driving it.
Crude-by-rail has saved the day for Alberta producers before, and it’s about to again. The talk of the Western Canadian province the past few days has been the Alberta government’s October 31 announcement that it will allow incremental crude oil production beyond the province’s 3.8-MMb/d cap — if that crude is transported to market by rail. Within hours of the government’s statement, a trio of major producers indicated that they now expect to ramp up their Alberta output by a total of more than 100 Mb/d over the next few months, with a good bit of the gain occurring by year’s end. Production increases from others are likely to follow, as are parallel plans to load that crude into tank cars and rail it to market. But can Alberta producers really thrive without more pipeline capacity? Today, we review recent developments in “Canada’s Energy Province” and what they mean for producers and Alberta crude prices.
The ready availability of low-cost propane, the expectation of renewed growth in global propylene demand and other factors are spurring development of another round of propane dehydrogenation plants in North America. Three PDH plants — two in Alberta and one in Texas — already are under construction and scheduled to come online in the 2021-23 period. Now, Enterprise Products Partners has committed to building a second PDH plant at its NGL/petchem complex in Mont Belvieu, TX, and PetroLogistics — which completed the U.S.’s first PDH plant in 2010 — has selected the technology it will use for a new facility it now plans to build along the Gulf Coast. Today, we discuss planned PDH capacity additions in the U.S. and Canada and what’s driving their development.
To hear proponents of Uinta Basin waxy crude oil tell it, all that’s keeping the hydrocarbon-packed region in northeastern Utah from significantly increasing production in the 2020s is a better way to transport their shoe-polish-like crude to Gulf Coast refineries than trucking to existing transloading facilities. And now, they think they’ve finally found it. If all goes to plan, by early 2023 a new, 85-mile short-line railroad will be in place to move at least two 110-car unit trains of waxy crude a day from the epicenter of Uinta Basin production to interconnections with two long-haul rail lines. That would give producers significantly enhanced access to markets far beyond the five Salt Lake City-area refineries to which they now truck some 90% of their output. Today, we conclude our series on the Uinta Basin with a look at the proposed Uinta Basin Railway crude-by-rail project and what it would mean for the play’s producers, as well as for Gulf Coast refiners.
Every so often, there’s talk that the crude oil hub in Cushing, OK, isn’t as important as it used to be. Don’t believe it. Want proof that Cushing is alive and well? Consider the growing list of pipeline projects into and out of the hub that have been coming online or advancing to final investment decisions, as well as the efforts to push Cushing’s storage capacity toward the 100-MMbbl mark. Midstream companies have committed to building more than 800 Mb/d of new pipeline capacity from Cushing to other hubs and to refineries, and another 1.6 MMb/d of capacity is in the pre-FID development stage. Today, we conclude a mini-series on recent developments at the Oklahoma oil hub with a look at storage expansions, new Cushing players, and outbound pipeline projects.
Each and every production region in the U.S. has its own unique geology, geography and hydrocarbon assets, but few, if any, are more unusual than the Uinta Basin in northeastern Utah. Physically isolated from all refining centers except Salt Lake City, the region boasts enormous reserves of waxy crude oil that’s been made accessible at a very low cost per barrel via horizontal drilling and hydraulic fracturing. While Uinta Basin crude looks, smells and feels like shoe polish, it has many characteristics that refiners want, including medium-to-high API gravity and very low sulfur, acid and metal content. There are two snags to expanding production, though: waxy crude poses major transport challenges, and Salt Lake City refineries can only use so much of the stuff. So if Uinta Basin producers want to increase production by much, they’ll need to develop cost-effective ways to move large volumes of their waxy crude to faraway markets like the Gulf and West coasts. Today, we continue a series on the prospects for expanding waxy-oil output with a review of Uinta Basin producers and their customers in the close-by “City of the Saints.”
Crude oil inventory levels aren’t the only thing in a constant state of flux at the crude storage hub in Cushing, OK. A year ago, we blogged extensively about Cushing’s major players, storage assets and incoming and outgoing pipelines, as well as plans for new pipes that highlight the hub’s continued significance, even in an increasingly Permian- and Gulf Coast-focused energy sector. A lot has changed since then, though. Some pipeline projects into and out of Cushing have advanced to final investment decisions (FIDs), while others have floundered or foundered. Also, brand-new pipeline projects have been announced, as was a big acquisition that will make Energy Transfer a major player in Cushing storage. Today, we begin a short series on recent developments at the Oklahoma oil hub and how they reflect changes in the ever-evolving U.S. energy markets.
New fractionation plants, steam crackers and export facilities are being built along the Gulf Coast, all spurred by rising U.S. production of natural gas liquids. This incremental NGL output and these new projects are putting serious pressure on existing NGL pipeline and storage infrastructure, and prodding the development of new salt-cavern storage capacity for mixed NGLs, NGL purity products, and ethylene and other olefins. Also, new, expanded and repurposed pipelines to enhance NGL-related flows throughout the region are in the works. Today, we continue our series on NGL storage facilities along the Gulf Coast with a look at Easton Energy Services’ plans for more underground storage capacity in Markham, TX, and new NGL and olefin pipelines.
During the 2010s, the Marcellus/Utica region has experienced an astonishing 16-fold increase in natural gas production, from 2 Bcf/d in early 2010 to more than 32 Bcf/d today. The region’s rapid transformation from minor energy player to superstar came with a lot of infrastructure-related growing pains, many of them tied to the urgent need for more gas pipeline takeaway capacity. Takeaway constraints have largely been addressed — at least for now — but producers’ continuing efforts to develop “wet,” liquids-rich parts of the Marcellus/Utica have resulted in an ongoing requirement for more gas processing and fractionation capacity. Put simply, as wet-gas production ramps up, so must the region’s ability to process that gas and its associated natural gas liquids. Today, we continue a series on existing and planned gas processing and fractionation projects in the Northeast with a look at the growing role played by Williams and its new Canadian partner.
There already are indications that newly available takeaway-pipeline capacity out of the Permian Basin is goosing crude oil production growth there. Flows on those new pipes — Plains All American’s Cactus II and the EPIC system — are ramping up, crude exports are setting new records, and the end of big price discounts for oil at Midland versus Cushing and the Gulf Coast are giving Permian producers an economic incentive to produce more. And more takeaway capacity is on the way, including the 900-Mb/d Gray Oak Pipeline, which is slated to come online in the fourth quarter. Fast-rising production is putting new pressure on producers and their midstream partners to build and expand crude gathering systems and shuttle pipelines — especially in the Permian’s Delaware Basin, which has a lot less gathering pipe in the ground than the Midland Basin and which is poised for phenomenal production growth the next few months and years. Today, we discuss highlights from our second Drill Down Report on Permian gathering systems, this one focusing on developments in the fast-growing Delaware Basin in West Texas and southeastern New Mexico.
A build-out of NGL fractionators, steam crackers and export terminals for ethane, LPG and ethylene is actively in progress along the Gulf. This growth is spurring the development of new storage capacity — not just at the Mont Belvieu NGL hub, but in other, nearby areas with access to fracs, crackers and export docks. Much of this new storage capacity is being developed by companies that fractionate mixed NGLs and sell so-called “purity products” to meet their internal needs. However, at least one project is being built by what you might call an “independent,” whose aim is to connect to multiple pipelines and provide storage services to customers, without taking title to products alongside their customers. Today, we continue our series on existing and planned NGL storage facilities along the Gulf Coast with a look at Caliche Development Partners’ new storage complex in Beaumont, TX.
The Uinta Basin in northeastern Utah boasts enormous reserves of unusual, waxy crude oil with many characteristics that refiners desire: medium-to-high API gravity and very low sulfur, acid and metal content among them. Moreover, the combination of long horizontal wells and hydraulic fracturing now give producers access to the basin’s waxy crude at a remarkably low cost per barrel. The catch is that the crude’s most notable feature — its shoe-polish-like consistency at room temperature — poses a major economic and logistical challenge: how to cost-effectively transport the stuff to distant markets. Refineries in nearby Salt Lake City have been making good use of the waxy oil for decades, but there are limits to how much they can process, so Uinta Basin producers, midstreamers and investors have been working on ways to move large volumes to faraway places like the Gulf and West coasts. They may finally be making real progress. Today, we begin a series on the prospects for taking waxy-oil production from the often-overlooked Uinta Basin to the next level.
The Permian Basin has attracted more than its share of midstream start-up companies over the past few years, and for good reason. The region has experienced big gains in crude oil, natural gas and NGL production, and that’s put stress on the Permian’s already significant pipeline infrastructure and spurred the development of many new projects. One new midstreamer that’s made a big splash is Lotus Midstream, which, since it was formed in early 2018, has partnered with some of the Permian’s biggest players — including ExxonMobil and Plains All American — to advance the now-sanctioned 1.5-MMb/d Wink-to-Webster crude pipeline. It’s also acquired Occidental Petroleum’s (Oxy) Centurion pipeline system, which includes a lot of crude gathering pipe and is one of the two main takeaway links between the Permian and the Cushing, OK, hub. What’s Lotus up to, and how is it shaping Permian crude transportation? Today, we examine what has quickly become one of the largest midstreamers in the U.S.’s hottest shale play.
The “wet,” liquids-rich parts of the Marcellus/Utica region enable producers there to benefit from the sale of both natural gas and NGLs. The catch is that, unlike major production areas in other parts of the U.S., the Northeast has no pipelines to transport unfractionated, mixed NGLs — also known as y-grade — long distances to fractionation centers in Mont Belvieu, TX, or Conway, KS. As a result, midstream companies serving the region have developed a number of interconnected gas processing, NGL pipeline and fractionation networks within the wet Marcellus/Utica to efficiently and reliably deal with the increasing flows of NGLs coming their way. No one has done this on a larger or more impressive scale than MPLX, Marathon Petroleum Corp.’s midstream-focused master limited partnership. Today, we continue our series on recently completed and planned gas processing and fractionation projects in the Northeast with a look at MPLX, the regional leader in this space.