For the U.S. oil patch, exports are the lifeblood of today’s market. U.S. refineries are operating at more than 90% of their rated capacity and using as much domestically produced light-sweet shale oil as their sophisticated equipment will allow. That means that virtually all of the incremental U.S. unconventional light-sweet crude oil production will need to be piped to export terminals along the Gulf Coast, loaded onto tankers, and shipped to refineries overseas. In today’s RBN blog, we discuss what this undeniable link between crude oil exports and production growth means for U.S. E&Ps and midstream companies — and the future of the oil and gas industry.
Analyst Insights are unique perspectives provided by RBN analysts about energy markets developments. The Insights may cover a wide range of information, such as industry trends, fundamentals, competitive landscape, or other market rumblings. These Insights are designed to be bite-size but punchy analysis so that readers can stay abreast of the most important market changes.
Memorial Day in the U.S. and the annual spring bank holiday in the U.K. put a wet blanket on Monday’s crude oil markets. Brent was off about $0.68/bbl as of mid-afternoon in thin holiday trading. That follows a rebound on Friday, when Brent moved $0.69/bbl higher to settle at $76.95/bbl and WTI was up $0.84/bbl to settle at $72.67/bbl.
May was a tough month for US oil and gas rig count, with producers ending the month with a fourth consecutive weekly decline (-44 vs April 28). Total US rig count was 711 for the week ending May 26, according to Baker Hughes. Rigs were added in the Permian (+1) and Eagle Ford (+1) this week, while the Anadarko (-5), Haynesville (-3), Gulf of Mexico (-1) and All Other Basins (-1) all posted declines. Total US rig count is down 42 in the last 90 days, and down 16 vs. this same week a year ago.
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Daily Energy Blog
It wasn’t that long ago that Western Canada was awash in propane, sending the vast surplus for export by railcar to the U.S. That has changed in the past two years as direct exports to Asia opened up and Canada’s domestic demand for propane rose. With supplies becoming tighter, the combined effect with increasing demand spells trouble for higher exports to the U.S. this winter, a time when they are desperately needed. In today’s RBN blog, we explore the current Western Canadian propane market and what might be next in store.
The high-demand season for propane is just around the corner: crop drying, then winter heating demand. This is when propane marketers make most of their money; so under normal circumstances it’s a happy time, when all participants across the supply chain are making last-minute preparations for the season of peak propane demand. But this year is different. There is palpable concern in the market about the level of inventories available to meet demand, and the possibility that propane could be in short supply. How could this be? As we have covered many times in the RBN blogosphere, U.S. propane production is more than double domestic demand. So how could a shortage possibly happen? The answer is pretty simple: exports. The U.S. exports more of its propane production than it uses here at home. This year the domestic market needs more barrels, so all that needs to happen is for U.S. prices to increase enough to shut off exports, right? Wrong. Propane prices have been spiraling up all year, and August prices are higher than they’ve been since 2013. But exports are still running strong, and so far, inventories are not building fast enough. In today’s blog, we’ll look at the drivers behind this seeming market aberration and consider why the upcoming winter season looks like uncharted territory for propane marketers.
Supplies of natural gas liquids, especially propane, have become increasingly tight in recent months, with prices reaching multi-year highs in the U.S. and Canada. Despite the strong price signals, increasing production is typically a lengthy, complex, and expensive process involving producers drilling new wells to yield more liquids-rich natural gas and crude oil. There is also another way to increase supplies: by extracting them from already processed and pipelined natural gas via a straddle plant that more intensively recovers additional NGLs, such as propane, from the existing gas supply. Canada’s Wolf Midstream has recently sanctioned such a plant, as well as a related pipeline and extraction plant in Alberta that it hopes to bring into service in 2023. In today’s blog, we examine this new straddle plant and Western Canada’s current propane supply situation.
The EIA report on propane inventories that came out yesterday was a shocker. This time of year, stocks are supposed to be building toward the levels needed to get U.S. propane markets through the winter season. But the numbers released on Wednesday showed an inventory decline, resulting in inventory balances now below the five-year minimum. The culprit, of course, is exports, with 1.4 MMb/d of them reported last week, a 17% gain over the year-to-date average. And these cargoes to overseas markets are happening even with propane prices in the stratosphere: more than double where they stood this time last year. Propane marketers were hoping that higher prices would slow down exports, but so far that is not happening. In today’s blog, we examine U.S. exports of LPG — propane plus butane — and discuss what may be ahead for these markets.
Fourth of July skyrockets were not the only fireworks earlier this week. The price of propane skyrocketed up to 112 c/gal before the holiday weekend and held at that level through Tuesday, an increase of about 21 c/gal or 23% over the past month alone. To put that in perspective, that’s the highest price for propane since April 2014, back when crude oil was over $100/bbl. Although propane came off a few cents on Wednesday in sympathy with falling crude prices, both Mont Belvieu and Conway propane prices are still almost 135% higher than this time last year. Assuming crude prices don’t fall off a cliff, how high could propane prices go? Hard to say. The propane market is experiencing unusually low inventories, relatively modest production growth, near record-high export volumes, and unconstrained dock capacity. Consequently, if we continue to see strong demand, but U.S. producers stay focused on capital discipline, thus constraining production, propane prices could be headed considerably higher this winter. Today, we continue our series of deep dives into the U.S. propane market and, in a blatant advertorial, describe how you can keep up with this rapidly moving market with RBN’s new Propane Billboard report and dataset.
Propane prices at Mont Belvieu soared above $1/gallon on Wednesday — the first time that’s happened in the month of June since 2014. This buck-and-change price doesn’t come as much of a surprise for industry insiders, however. U.S. propane inventories have been very skinny lately, sitting at 56.2 MMbbl — or only 587 Mbbl above the five-year minimum based on yesterday’s EIA data. At the same time, propane exports have been riding high, averaging 1.3 MMb/d so far this year, up nearly 90 Mb/d from the same time frame in 2020, while production has remained virtually flat over the past 18 months. Surprise or not, the spike past $1/gal raises an important question: How high will U.S. propane prices have to go before exports are reined in so U.S. inventories can increase? Today, we discuss the key drivers behind the current price level and our propane market outlook for the second half of the year.
So far in April, there was an unexpected run-up in propane prices early in the month, followed by a 21% swoon in the past 15 days of trading. The forward curve suggests smooth sailing from now through next winter season, but that seems unlikely, given recent market developments. Propane inventories, which are supposed to be building this time of year, actually fell last week, putting stocks at 16.9 MMbbl below this point in 2020, according to EIA statistics released last week. The data also showed that weekly exports spiked to the second-highest peak of all time at 1.7 MMb/d, while production declined two out of the past three weeks. And just over the horizon, there’s the potential for a big increase in Chinese propane demand as new petrochemical plant capacity comes online over the next three years. Today, we look at how these issues are likely to shape the propane market over the next few months and suggest that you consider attending our upcoming virtual conference, where we will pose these questions to industry leaders from production, midstream, exports, and retail market segments.
Wow, what a ride! That’s what came to mind yesterday as the 2020-21 propane season drew to its official end. But the excitement and uncertainty aren’t over, folks. Not by a long shot. Propane exports are still running sky-high; end-of-season inventories are at the low end, with a whopping 2-MMbbl withdrawal number in EIA’s stats yesterday; and a backwardated forward curve is not doing anything to encourage U.S. marketers and midstreamers to rebuild stocks. We get it — no one wants to think about next winter yet, just as spring is really springing. But still, you’ve got to wonder, could the dynamics that have been roiling the propane market be setting us up for skinny inventories and price spikes in the 2021-22 propane season? Today, we examine the challenges facing the propane market over the next few months.
It’s been over a month since the Deep Freeze swept across Texas, shutting down the power grid, curtailing natural gas supplies, and generally wreaking havoc on the state’s population and infrastructure. The petrochemical industry was hit particularly hard, with every ethylene-producing steam cracker in the state and many in nearby Louisiana forced into hard shutdowns — that is, production coming to a screeching halt with little or no preparation. The result was unit damage well beyond what typically happens with other weather-related events like hurricanes, where there is usually some ability to manage an orderly shutdown. Consequently, at least half of the industry’s capacity to produce ethylene and its by-products remains offline, a development that is ricocheting through supply chains across the economy. Today, we examine the magnitude of the damage, consider what is happening in ethylene markets — the epicenter of the turmoil — and contemplate the longer-term implications of the outages.
We started off this propane season worried about the threat to U.S. propane markets from big-time exports. With exports now exceeding total U.S. propane demand, how would propane markets respond if we ever got a really cold winter? Well, now we know. Frigid weather finally arrived in February with a vengeance. But the propane market handled it pretty well. Now, as we approach the end of propane winter and examine where the market stands with inventories, prices, and especially exports, the big question is, what happens next? Will production volumes replace depleted stocks now sitting near a five-year low, or will those barrels move overseas? Will strong global petchem demand pull supplies out of U.S. markets? And if so, what does that imply for the 2021-22 retail propane season here in the U.S. In today’s blog, we’ll begin an exploration of these issues and introduce our upcoming RBN virtual conference covering developments in the propane market scheduled for May 12. Warning! Some of today’s blog is an unabashed advertorial for the conference.
Here in Texas, the snow is melting, the power is back on, and some of us even have drinkable water. We’ll be dealing with the aftermath of the 2021 Deep Freeze for months, and talking about the insane natural gas and power prices for as long as gas and power markets exist. One thing you have not heard much about during these crazy few days is propane. And given what we’ve been through, no news is good news. Sure, it was impossible to exchange a tank at the local Quickie Mart, and there were sporadic reports of delayed propane deliveries and local shortfalls. But even up in the coldest Midwest states, there were no market meltdowns, no skyrocketing prices. Instead, propane has been the go-to fuel to keep folks warm, to get energy production moving again by defrosting wellheads and pipeline valves, and even to get restaurants back on their feet. It’s always dangerous to declare a winter victory with a few weeks left to go in the season, but today we’ll take that risk.
A blast of Arctic air plunges the Midwest and Northeast into deep freeze. Already-low propane inventories result in supply shortages in local markets. Propane transport trucks move product hundreds of miles from storage hubs to replenish regional terminals as markets scramble to meet surging propane demand. Are we talking about the nightmarish polar vortex winter of 2013-14, when regional propane inventories were sucked down dangerously low and Conway, KS, propane prices skyrocketed to almost $5.00/gal? No. We are talking about now. This is a description of what is happening today in U.S. propane country –– that belt of northern states that depend heavily on propane for heating. But this is not 2013-14. Things have changed. So in today’s blog we’ll explore how the latest polar vortex could be quite different than that weather-driven crisis seven years ago.
It’s a well-known fact in the energy and petchem industries that ethane is either “rejected” into natural gas or used as a feedstock for steam crackers. But piping ethane to NGL hubs, crackers, or export docks only makes sense if it’s economically viable or if there’s no other alternative, and ethane rejection has its limits — ethane has a 70% higher Btu value than methane, and too much rejection can make pipeline gas “too hot” for downstream consumers. Well, there’s another way to make economic use of ethane: burn it — typically in a blend with natural gas — to generate electric power. Burning ethane for power is super-rare though, and only happens in places where the lightest of all NGLs is so abundant that folks don’t know what to do with it. The Marcellus/Utica region in Appalachia for one, and now — just maybe — the Bakken Shale in western North Dakota. Today, we discuss plans for what would be only the second major U.S. power plant to be fueled by a blend of natural gas and ethane.
Things move fast in today’s propane market. Two weeks ago, Mont Belvieu propane was going for almost 95 cents/gal, up 86% from the mid-November price of only 51 c/gal. Midcontinent propane assessed in Conway, KS, spiked even higher, doubling over the same time frame to more than a dollar per gallon. But last week some air came out of the balloon, with Mont Belvieu and Conway prices pulling back to the low 80s. That didn’t last long either. This week, Mont Belvieu is back up to the high 80s c/gal. What gives? Is the market simply being bounced around by vacillating weather forecasts? Or is there more to it than that? Could it be that we are seeing symptoms of an export-driven transformation that is making propane markets behave quite different than they have in the past? Today, we’ll consider these questions and where the propane market may be headed in 2021 and beyond.
After several years of development, Shell’s $6 billion Pennsylvania Petrochemicals Complex — the first of its kind in the Marcellus/Utica shale play — is really taking shape about 30 miles northwest of Pittsburgh. The facility, which will consist of a 3.3-billion-lb/year ethylene plant and three polyethylene units, is in its final stages of construction, as is a pipeline that will supply regionally sourced ethane to the steam cracker. When the Falcon Pipeline and the PPC comes online, possibly as soon as 2022, they will provide a new and important outlet for the vast amounts of ethane that is now either “rejected” into natural gas for its Btu value or piped to Canada, the Gulf Coast, or the Marcus Hook export terminal near Philadelphia. Today, we discuss progress on the Marcellus/Utica’s first world-class petrochemical complex and what it will mean for the play’s NGL market.