With the prospect of associated gas from the Permian and Eagle Ford diminishing, many producers view the future of dry gas plays in the Appalachian Basin more positively. Those well-positioned and well-capitalized companies are staring at an unexpected opportunity.
As E&Ps jam the brakes on capex spend, the largest U.S. oilfield service providers respond in unison, cutting costs where they can and laying down equipment where they must.
In a market environment where buyers and sellers are at odds over price and the public market is openly hostile to deals, E&P shoppers may sit out an uncertain 2020.
Some say broader environmental, social and governance measures are a must in support of a global decarbonization campaign.
Smaller Midland Basin operators discuss longer laterals, parent-child, lowering per-foot costs, evaluating additional targets and field operations efficiencies.
There goes the neighborhood? In early spring 2019, Exxon Mobil announced it would turn its Permian Basin position into a kind of dreadnought, raising questions about how it will coexist with its neighbors.
Operators are learning the hard way that parent-child well interaction is damaging to both their field developments…and their bottom lines.
Oklahoma producers are intensifying multisection-lateral and multizone development of their liquids-rich leasehold, bringing production nearer to first spend. They’re also paring costs by millions per well.
Harold Hamm has taken on many challenges, including lifting the oil export ban and proving the viability of the Bakken, but his latest may be his most daunting: explaining Trump.
Public E&P investors are insisting that operators produce returns, so private-equity-backed E&Ps wanting to sell to a public E&P are working to do the same. One said, “It all rolls downhill.”
The Bakken’s operators are seemingly locked into a dwindling geography in North Dakota, but companies are increasingly returning to their wildcatter roots to see how far they can stretch the Williston Basin’s core.