In this post, we examine some of the most discussed items and trends from the Q1 2020 earnings calls, specifically those in the mineral aggregator space.
In this post, we examine some of the most discussed items and trends from the Q1 2020 earnings calls, specifically those in the mineral aggregator space.
In this post, we examine some of the most discussed items and trends from E&P companies’ Q1 earnings calls.
The fact that valuations in the mineral and royalty space have decreased is not news at this point, but what is interesting is that this environment has changed a lot of things along the way.
The recent historic decline in oil prices has strained the balance sheets of E&P companies. Whiting Petroleum Corporation, the first publicly traded U.S. E&P company to declare bankruptcy in 2020, announced its Chapter 11 reorganization process on April 1. More are expected to follow.
Despite a much more benign commodity price environment of ~$50-$60/bbl in 2019, a number of E&P companies declared bankruptcy last year and have seen their reorganization processes derailed in 2020 as a result of low oil prices.
Times are tumultuous for the oil and gas industry. News earlier this month was met with no rise in West Texas Intermediate pricing at the time. It hovered around $20.00 per barrel. Last week it fell to the seemingly unconscionable negative territory. It was worse in other places. In Western Canada heavy select oil was around $4.50 per barrel and dropped to $0 last week. It went negative as well. World demand for oil has dropped somewhere between 20% and 35% by some estimations, and excess supply has been building for weeks.
Something must give, and something will. While global supply and demand imbalance has the industry scrambling in unseen territory, how does this convert to what upstream companies and reserves are worth amid the situation? Is it a 1:1 price to value change ratio? Depending on perspective, the answer is both simple and complicated.
It’s been a truly dizzying time in the rough-n-tumble world of oil production. Like they say, if you miss a day, you miss a lot. For now, it at least appears that someone may have just blinked. The Trump administration seems to be on the verge of a truly historic deal to cut worldwide oil production and bring oil prices up to a modestly workable level. And that with the U.S. not committing to forcing domestic producers to cut production levels but indicating that U.S. production would “naturally” decline without the government’s intervention. That coupled with a potential side-deal with Mexico to “cover” part of the production decrease that was being sought from that country, but that Mexico is unwilling to shoulder on its own. Will it work? Will the deal be accomplished? Although an agreement was reached to reduce oil production in light of demand destruction caused by the coronavirus pandemic, oil markets appear to remain oversupplied. Will OPEC+ and other nations agree to another deal to further reduce production? Will U.S. production decline faster than anticipated due to low oil prices? Will the Texas Railroad Commission implement proration orders for Texas producers? All we can say is, stay tuned – and expect the unexpected.
In this post we examine the macroeconomic factors that have affected prices in this first quarter.
The economics of oil and gas production vary by region. Mercer Capital focuses on trends in the Eagle Ford, Permian, Bakken, and Marcellus and Utica plays. The cost of producing oil and gas depends on the geological makeup of the reserve, depth of reserve, and cost to transport the raw crude to market. We can observe different costs in different regions depending on these factors. This quarter we take a closer look at the Eagle Ford.
Over the last year, deal activity in the Eagle Ford Shale was relatively steady, picking up towards the end of 2019 and carrying into early 2020. This week we discuss recent transactions in the Eagle Ford.
Energy valuations are taking an epic pummeling. Considering declining demand amid COVID-19 concerns, the initial fallout to the Saudi-Russia feud was predictable. Can Banks Hold On? Can Values Recover?
This week we discuss how commodity prices and recent events have impacted the Oil Field Services Industry, and what to expect going forward.
In this post, we examine some of the most discussed items and trends from the Q4 earnings calls, specifically E&P companies and those in the mineral aggregator space.
Have you downloaded Mercer Capital’s 2019 Energy Purchase Price Allocation Study yet? The study provides a detailed analysis and overview of valuation and accounting trends in these subsectors of the energy space. It enables key users and preparers of financial … Continued
Our previous posts on salt water disposal provided an overview of the sector and detailed the economics of the industry. In this post, we take a deeper dive into specific considerations that are critical to understanding the value of salt water disposal companies.
Understanding the value of an oilfield services (OFS) company is by its very nature a complex matter. In this post we discuss our latest whitepaper, Understanding Oilfield Services Companies & How to Value Them.
In this post, we focus on mineral aggregators. We also offer insights on the investment landscape at large and particularly as it relates to the minerals subspace by providing an update on the most recent IPO, Brigham Minerals (MNRL).
Last week, Mercer Capital released its 2019 Energy Purchase Price Allocation Study. In this post, we’ll be taking a deeper dive into the Exploration & Production transactions reviewed in the analysis.
We at Mercer Capital love movies. One fun aspect of a movie is the anticipation for new releases that comes from watching movie trailers, which inform and tease simultaneously. If done well, they can build anticipation for the show to come. While not quite a movie trailer, we wanted to introduce you to a new study from our energy team that we are excited about: Mercer Capital’s Energy Purchase Price Allocation Study.
Brent crude prices began the quarter around $59 per barrel and have steadily risen to around $68 to close out 2019. WTI pricing has risen at a similar pace although it continues to trail Brent pricing by about $7 per barrel. Natural gas, however, has been trending in the opposite direction as prices have steadily declined since the end of October. In this post, we will examine the macroeconomic factors that have affected prices in the fourth quarter.
U.S. dry gas consumption will finish at an all-time high in 2019 and will continue to grow in early 2020. When one observes valuations for gas producers in Appalachia, they can quickly become dispirited. How can economics get this jilted in arguably the largest gas field in the world?
As we plan for a new year and a new decade, we look back at 2019 to see what was popular with you – our readers. This week’s post includes a list of the top posts of 2019 grouped by topic (Transactions, Saltwater Disposal, Oilfield Services Companies, Royalty and Mineral Markets, and Basin-Specific posts). If you missed one or two posts during the year, now is the time to catch up on your reading.
It was a quiet year for M&A in Appalachia as only a handful of transactions occurred. Surging associated gas production in places like the Permian and Bakken have kept a lid on gas prices, which have largely remained between $2 and $3/mmbtu for the year. Near term expectations aren’t much better, with futures prices below $3 through 2029. Management teams were likely preoccupied with various corporate and capital structure issues instead of changes to the underlying reserve base. However, a bright spot is the easing of takeaway constraints that previously plagued the region.
The energy sector in the third quarter has experienced a general decline as crude prices have exhibited volatility and have remained depressed relative to last year. U.S. producers continue to cut rigs and capital expenditures due to continued excess supply and concerns of declining demand. In this post, we examine some of the most discussed items and trends from the Q3 earnings calls, specifically E&P companies and those in the mineral aggregator space.
While equity prices have dropped by approximately 30% for producers, six publicly-traded royalty aggregators relatively outperformed the SPDR Index. These Royalty MLP’s have tracked closer to crude oil prices, anchored by sizeable dividend payments, thus buoying sliding equity prices. If dividend yields are added back, some of them have been outperforming crude prices.
