As the deal count stumbles to near a two-decade low, we saw a lot of activity in the M&A space during the first part of 2023. The need for E&P companies to expand their inventory revived the market. While the second half of 2022 was dominated by large-cap public company deal flow, small and mid-cap companies have taken over so far this year.
What changed and what factors are influencing the industry outlook for the remainder of the year?
Much of the central narrative remains the same with management and investors focusing on building a robust inventory and demanding return on capital via share buybacks and dividends.
On the buy side, large-cap companies—with a market capitalization of $10 billion or more—showed their balance sheet strength and favorable stock valuations to execute deals that were both accretive to current cash flow and that expanded their drilling locations.
For small-mid caps (SMID), solving the inventory dilemma wasn’t as simple. Their modest equity trading makes it challenging to put in an aggressive offer that values inventory while keeping the deal accretive. We’re seeing a trend where companies are turning to more creative strategies, including deals in which non-op Northern Oil & Gas partnered first with Vital Energy to acquire Forge Energy II; then played a similar role in Earthstone Energy Inc.’s successful acquisition of Novo Oil & Gas Holdings LLC in August.
Trading assets allowed Callon Petroleum to become a Permian pure-play company while Ridgemar Energy Operating LLC, backed by Carnelian Energy Capital Management LP, struck their first deal in the Eagle Ford. Similarly, Encap Investments was able to pick up Williston Basin assets for Grayson Mill as part of their agreement to sell their trio of Midland Basin portfolio companies to Ovintiv.
On the sell side, private equities led the way and continue to take advantage of the momentum created as public buyers focused on securing future drilling inventory. Stable commodity prices along with the need to exit mature investments and show returns to limited partners as private equity firms raise new funds contributed to the success of this strategy.
Oil prices are no longer at an impasse between buyers and sellers. If prices can stay range-bound in the 70s to 80s, we will continue to see an active M&A market and further consolidation. Size and scale matters: inventory in core plays will likely increase in value as fewer quality positions with scale are available.
Corporate consolidation should prompt secondary transactions to sell off the assets considered non-core relative to the acquisition targets. This should provide some relief to what otherwise has been a slow start of the year for the A&D middle market.
Public buyers, particularly SMID caps, are using cash and increasing leverage to pursue accretion. We expect this trend to continue until their share price valuation is more favorable.
Oil and gas banking gap?
Credit terms remain conservative, often requiring a 50-50 debt-to-equity split for acquisition finance. While syndications are challenging, these multi-bank financings are getting done with increasing effort to secure participants.
The bread and butter of the energy banking industry has and will continue to be A&D activity.
Since 2016, the number of banks with dedicated upstream lenders has declined. Foreign banks have either retreated or reduced their energy exposure due to significant losses or pressure to reduce exposure to fossil fuels.
The energy banks that remain have re-examined how they deploy capital. Some larger banks have moved up market in search of large commitments, investment banking opportunities and large one-time fees. Midsized banks have focused on funded debt, deposits and cross-sales to privately funded oil and gas companies.
As banks redefine their target clients, multibank syndications align with specific client’s business objectives.
Regional banks do not want to be 2% of a large billion-plus dollar credit facility while money center banks have little interest in smaller companies with no potential for capital markets.
So, is there a banking gap? It depends.
Saying there is a traditional lending gap is too simplistic. The shifting bank market based on company size is more apparent now. Producers’ expectations will ultimately determine proper alignment with the new banking dynamic. Without proper alignment, the producer has additional capital optionality outside regulated banks.
For a traditional reserve-based lending (RBL), producers should expect consistent credit terms, the need to bid out services across the syndicate and the importance of a bank’s internal risk assessment.
Much like private producers revolutionized the shale boom, regional banks remain the backbone of RBL.
Those lenders who remain steadfast in their commitment to upstream oil and gas will continue to support the next generation, albeit with more business expectations in return for bank capital.
Mari Salazar is the manager of energy banking at BOK Financial and Cristina Stellar is managing director of energy investment banking at BOK Financial Securities.
2023-09-29 - The Biden administration’s proposed 2024–2029 National Outer Continental Shelf (OCS) Oil and Gas Leasing Program would allow for the “smallest number” of offshore oil lease sales — three — in the history of five-year programs.
2023-10-05 - The Bureau of Ocean Energy Management’s Gulf of Mexico lease sale is set for Nov. 8 and includes more blocks and acreage than the bureau’s earlier offering.
2023-10-26 - The order was the latest in a legal fight over offshore drilling and federal protection of an endangered species of whale.
2023-10-12 - The Bureau of Ocean Energy Management is seeking input to identify potential impacts of offshore oil and gas activities.
2023-09-26 - A U.S. appellate court has ordered that a Gulf of Mexico oil and gas lease sale must take place no later than Nov. 8.