Royalties

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. 

On average, the landowners and other entities that own mineral and royalty interests in producing oil and gas wells receive about 20% of the gross revenues generated by those wells — and do so without any responsibility for the significant costs and complications associated with well development and production. Mineral and royalty interests have traditionally been a highly fragmented market, with most held and passed down through generations by landowners or purchased by individual investors. However, competition for these interests has become more heated in recent years with the creation of large publicly owned and private-equity-funded consolidators and a new emphasis by E&P companies on adding these higher-margin slices of revenue from leases they own and operate. In today’s RBN blog, we explain mineral and royalty interests and analyze the developments in this massive $700 billion market.

Natural gas and oil development, especially in shale plays that require a lot of wells and a lot of activity, can be inconvenient and noisy.  There are also, of course, various criticisms and protests around some of the processes used, such as hydraulic fracturing, and around the overall level of activity, such as truck traffic.  The gas and oil producing industry values strong relationships with the communities where it needs to work, and can use all the friends it can get as it takes the lead in developing the nation’s vast energy resource.  Bringing big economic benefits to those communities, which are often rural or industrial areas hard-hit by economic downturns, is clearly really important in the efforts to build those relationships and friendships.  There are a lot of different kinds of economic benefits deriving from supply development, but by far the most important to the affected landowners are the royalties resulting from private mineral rights.  Today we continue our examination of the inner workings of oil and mineral rights issues, this time considering some common oil and gas royalty disputes.

There has been a great deal of publicity around royalties involved with the shale gas—stories of instant millionaires (or “shaleionaires,” as 60 Minutes called them in 2010), stories of producers reducing or even eliminating some royalty payments as the vast oversupply of natural gas took hold in the last couple of years, stories of long, excruciating negotiations to reach a royalty/lease agreement, only to find out that the seller’s side of the table didn’t actually contain the owner of the rights, and stories of neighbors turning on each other when they got radically different deals based on timing or whom they were dealing with, and so on.   Unless you have been directly involved in leasing and royalty work, a lot of it can be confusing.  So today we begin a blog series to illuminate the world of mineral rights, oil & gas leases and royalties.

Oil and gas shale production economics are creating an era of low cost energy in the US. But how do you decide if drilling one well is any more profitable than drilling another well next door or in a different basin? Just like with any other investment opportunity you compare net present values (NPV) and internal rates of return IRR). Today we continue our rundown of shale production financial return calculations with a review of variable production costs and NPV.