The Energy Mergers & Acquisitions Review: USA


i Oil and gas

The oil and gas industry is composed of four separate but related sectors:

  1. upstream (companies engaged in the business of extracting hydrocarbons);
  2. midstream (companies engaged in the business of transporting hydrocarbons);
  3. services (companies engaged in the business of assisting upstream and midstream companies with the extraction and transportation of hydrocarbons); and
  4. downstream (companies engaged in the business of refining petroleum after extraction).

For a number of reasons, 2020 has been a difficult year for the oil and gas industry. The year started off with promise but quickly turned negative when, in March 2020, the OPEC+ countries engaged in a relatively brief but damaging price war, which resulted in oil prices falling over 60 per cent. Shortly after the initiation of the OPEC+ price war, the world was ravaged by the covid-19 pandemic, which dramatically supressed the demand for oil and natural gas. This resulted in a dramatic increase in the number of bankruptcies for such companies and a precipitous drop in M&A activity in the industry. Beyond concerns related to the commodity price drop and global pandemic, the investment community has continued to withdraw from the oil and gas industry because of concerns over sustainability, high levels of debt, the lack of free cash flow at many of these companies, and environmental, social and governance (ESG) issues. These concerns have created further downward price pressure on oil and gas company stocks and would in turn lead to reduced operational and financial growth generally for companies in the oil and gas industry.

The equity and debt capital markets have continued to remain closed for most oil and gas companies, with the exception of those companies with the best credit profile. Investors are looking for low levels of indebtedness, visibility to free cash flow generation and a return of capital through share repurchases or dividends, which many oil and gas companies cannot provide. Private equity investment in the oil and gas industry has slowed somewhat in 2020 as compared to prior years, but these companies continue to offer an alternative source of financing through the use of various deal structures, including drillcos, wellbore securitisations and non-op joint ventures.

ii Power and utilities

Consistent with M&A volumes and value generally, the power and utilities sector saw a reduction in M&A activity in the first half of 2020 when compared to 2019 levels, both in terms of deal activity and deal value, in part because of the covid-19 global pandemic, a drop in commodity prices and general uncertainty in terms of market outlook and liquidity.2 In fact, 2020 deal activity and volume figures have fallen below historical averages, with M&A deal volume in Q2 2020 falling to the lowest levels in the last four years.3 Prospective buyers and sellers focused much of their attention in the first half of 2020 on the safety of personnel, implementing business continuity plans and seeking to assess the impacts of the pandemic. As of the time of writing, there appears to be a significant uptick in M&A activity in the second half of 2020, but deals in the second half of 2020 are not likely to make up for the slowdown in the first half of 2020. Asset deals have continued to be a primary driver for M&A activity for power and utilities in 20204 – this has been a trend since 2018 which, when combined with lower deal values as seen in 2020, signals a continued slowdown in consolidation in the sector generally since the most recent utility M&A wave in 2015 and 2016. In addition, in part because renewables businesses have been relatively shielded from the impact of the pandemic but also because of the continuation of improvements in technology, favourable regulatory policies and investor commitments, renewables deals have continued to drive a significant portion of US power and utilities sector deal activity.

Strategic deal count marginally exceeded deal activity of private equity and other financial investors in US power and utilities M&A throughout 2020, yet the latter contributed to a significant portion of deal value over the same period. In fact, one of the largest deals in terms of value for 2020 is Brookfield Renewable Partners' US$8.3 billion acquisition of a 38.5 per cent stake in TerraForm Power by merger.5 The expectation is for private equity and other financial investors to continue to play a larger and more significant role in power and utilities M&A, in large part because of capital deployment needs of infrastructure-focused funds, which have grown significantly in number and size. Over 250 infrastructure-focused funds were seeking over US$200 billion in capital from investors at the start of 2020, and because of the substantial growth in infrastructure investing in recent years, assets under management by infrastructure funds are on track to reach over US$1 trillion by the end of 2022.6

Despite a slowdown in US power and utilities M&A in 2020, renewable energy continues to play an increasingly important role in the US power and utilities sector. Renewable deals drove nearly 75 per cent of US power and utilities M&A activity in the first half of 2020.7 Additionally, the renewable energy sector experienced a very active development pipeline in 2020 despite macro-economic factors such as the covid-19 pandemic. New development is likely to drive even more M&A activity in years to come. The US solar sector has continued significant growth in utility-scale solar power projects in 2020, reaching over 42,000MWs of total installed utility-scale solar power capacity by the end of Q3 2020, tripling the amount of such capacity when compared to 2015, while the US wind project pipeline is expect to add over 30,000MWs in 2020.8 Policy shifts at all levels of the government and among investors in the US have – and will continue to have – meaningful impacts on renewable energy M&A activity. This undoubtedly will be accelerated under an administration led by President-Elect Joseph R Biden, Jr. who announced during his campaign a US$2 trillion Plan to Build a Modern, Sustainable Infrastructure and an Equitable Clean Energy Future.9

Year in review

i Oil and gas

Asset-level M&A activity has been relatively anaemic during 2020, reflecting a marked drop-off from 2019. Asset deals have been difficult to accomplish because of low commodity prices, the continuing effects of the covid-19 pandemic and a disconnect between buyer and seller expectations, which are driven by different views on the level and trajectory of commodity prices in 2021 as well as potential regulatory constraints that could arise at the federal and state levels, particularly given the transition to a new Democratic administration in the United States. There is a generalised concern that a Democratic administration could lead to limitations on the use of hydraulic fracking technology in the extraction of oil and natural gas and overall greater environmental regulation in general. State concerns stem from similar issues around hydraulic fracking, and also from additional issues related to drilling setbacks and disposal wells.

In 2020, strategic deals – those involving public companies in the oil and gas industry – have been down as well, and investor reception of the deals that have been announced was mixed. Transactions where the consideration reflects a premium to the unaffected stock price prior to signing have been met with severe scepticism by investors, while transactions where the consideration reflects no or a low premium to the unaffected stock price prior to signing have been received more positively but still with some scepticism. Some of the strategic deals in 2020 included:

  1. Chevron Inc's acquisition of Noble Energy Inc in an all-stock transaction (upstream);
  2. Southwestern Energy Company's acquisition of Montage Resources Inc in an all-stock transaction (upstream);
  3. the merger of equals transaction between WPX Energy Inc and Devon Energy Corp (upstream);
  4. ConocoPhillips' acquisition of Concho Resources Inc in an all-stock transaction (upstream);
  5. Callon Petroleum Corp's acquisition of Carrizo Oil and Gas Inc in an all-stock transaction (upstream);
  6. Parsley Energy, Inc's proposed sale to Pioneer Natural Resources Company in an all-stock transaction (upstream); and
  7. Schlumberger Limited's spin-off of its One Stem business to Liberty Oilfield Services Inc (services).

ii Power and utilities

Asset deals involving natural gas transmission and storage contributed significantly to the M&A activity in the US power and utilities space over the past year: Dominion Energy's agreement to sell substantially all of its gas transmission and storage segment assets to an affiliate of Berkshire Hathaway Inc in a transaction valued at US$9.7 billion (including the assumption of US$5.7 billion of debt) and NiSource's agreement to sell natural gas assets of Columbia Gas to Eversource Energy for US$1.1 billion are some of the largest of these asset deals. Strategic buyers continued to be most active in the US power and utilities sector generally, with these buyers also focused on electric transmission and retail energy. For example, NRG Energy reached an agreement in Q3 2020 to acquire Direct Energy, a North American subsidiary of Centrica, for US$3.625 billion in an all-cash transaction and NextEra Energy Transmission Investments announced an agreement in Q3 2020 to acquire GridLiance, a pure-play electric transmission business. Lastly, a number of transactions involving financial buyers, including Southwest Generation's acquisition of a 760MW combined-cycle power plant from Excel Energy for US$680 million, Brookfield Renewable Partners' acquisition of a 192MW Hydroelectric Facility in Louisiana for US$560 million and Energy Capital Partners' acquisition of CenterPoint Energy Services, CenterPoint Energy's natural gas retail business, for US$400 million, and Warburg Pincus' US$300 million investment in Scale Microgrid solutions, a distributed energy provider, illustrate the continuing shift of financial investors in the US power and utilities sector targeting a combination of gas and renewable assets in line with decarbonisation and other ESG initiatives and goals.

Finally, we would be remiss if we did not mention the surge in initial public offerings for special purpose acquisition companies (SPACs) that has dominated 2020, a number of which have identified clean energy, alternative energy, climate change, energy transition, ESG, sustainability or some combination of the foregoing as their focus. While not strictly M&A activity, it is significant insofar as it creates additional M&A opportunities for companies operating in (or contributing to growth in) the renewable sector as these SPACs must consummate their de-SPAC mergers within a short investment period (generally two years). Examples of de-SPAC mergers recently announced in this space include the merger of EV charging company ChargePoint with Switchback Energy, and battery developers QuantumScape and Eos Energy Storage with Kensington Capital and B. Riley Principal Merger Corp II, respectively.

Legal and regulatory framework

As with M&A more broadly, the legal framework for energy M&A involves concurrent regulation under a variety of federal and state laws.

M&A in the energy industry (both oil and gas and power and utilities) are regulated at both the state and federal level. At the state level, approvals are typically required under applicable corporate laws where each entity to the transaction is organised and, in the case of certain portions of the power industry, approvals by local public utility commissions. At the federal level, strategic transactions receive the most scrutiny typically associated with the solicitation of votes from shareholders, the registration of shares being issued as consideration and the disclosures required for a fully informed vote by shareholders.

M&A in the energy industry are also subject to antitrust laws, as discussed in Section VIII.

The energy regulatory frameworks applicable to energy M&A activities vary between upstream oil and gas E&P, midstream oil and gas infrastructure, and power assets.

Energy M&A activity involving upstream oil and gas exploration and midstream infrastructure is governed by a patchwork of state and federal laws and regulations. At the state level, the requirements vary by state, and are most often administered by a state's public utility commission, the state agency with jurisdiction over environmental matters, or both. For transactions involving upstream oil and gas E&P, the energy regulatory requirements generally are, in relative terms, not onerous. Those requirements typically involve the need to obtain approval from, or in some jurisdictions merely providing notice to, the relevant state regulatory body for the change in control or ownership of mineral leases, rights of way and other property interests involved in the transaction. If the transaction involves oil and gas exploration or production on federal lands, or in federal waters, there may be similar regulatory requirements at the federal level. Those federal requirements vary based on the type of federal lands or waters at issue (e.g., national parks, national forests, and waters of the Outer Continental Shelf) and the regulatory agency with jurisdiction over activities in such lands or waters.

Similarly, the legal framework for energy M&A activity involving midstream oil and gas infrastructure primarily consists of various state requirements. The states' respective regulatory requirements for energy M&A transactions range from minimal (for example, post-closing notification of a transaction) to significant (for example, requiring prior authorisation to consummate a transaction). Further, even among those states that require prior authorisation of such transactions, the timelines and standards of review used in those regulatory proceedings vary by state. At the federal level, there is no generic energy regulatory requirement applicable to energy M&A transactions involving midstream infrastructure. However, if a transaction involves changes to the physical or operational characteristics of, or the services provided by, a natural gas or oil pipeline that is regulated by the Federal Energy Regulatory Commission (FERC), those changes may require prior approval from FERC. Additionally, a change in ownership may require the filing of a post-closing notice at FERC, to the extent the change affects certain corporate information on file with the agency. Transactions involving the export or import of natural gas or oil can also trigger regulatory regimes administered by the US Department of Energy (DOE), the Marine Administration (MARAD) and the US Coast Guard (USCG), which may necessitate those agencies' prior authorisation of the transaction.

In contrast to the regulatory regimes for upstream and midstream oil and gas M&A transactions, the merger control regime for power (conventional and renewable) and utilities includes a robust federal regulatory programme. Depending on the specific assets involved in a transaction, prior authorisation for the transaction may need to be obtained from one or more regulatory agencies, including FERC, DOE, the Nuclear Regulatory Commission (NRC) and the Federal Communications Commission (FCC). Further, as with upstream and midstream oil and natural gas transactions, there is a patchwork of state legal and regulatory requirements applicable to energy M&A transactions involving power and utilities. Those requirements typically involve approval by the public utility commission or commissions in the states relevant to the transaction. At both the federal and state level, the regulators generally have the authority to impose conditions on a proposed transaction to ensure that the transaction is consistent with the public interest. It is not uncommon for regulators to exercise that authority, and the basis for doing so is most often to protect electricity consumers against potential, adverse rate impacts that could result from the transaction.

Cross-border transactions and foreign investment

The Committee on Foreign Investment in the United States (CFIUS) is an interagency committee authorised to review certain foreign investment activity in the United States and assess and mitigate any associated national security risks. CFIUS' authority is codified within Section 721 of the Defense Production Act of 1950, as amended (Section 721), and as implemented by Executive Order 11858, as amended, and the regulations at Chapter VIII of title 31 of the Code of Federal Regulations. While the CFIUS review process historically has been, and largely remains, voluntary, recent reforms that were fully implemented earlier this year include a mandatory filing requirement for certain transactions that involve 'critical technologies' or a foreign government controlled investor.

Thus, M&A activity in the energy industry can now trigger a mandatory filing obligation with CFIUS. Failure to submit mandatory filings with CFIUS can result in significant penalties (up to the total transaction value). Increased technical due diligence is required to determine whether (1) the US target company is involved with critical technologies that could trigger a mandatory filing or (2) a voluntary filing may be warranted. Among other things, this determination requires a detailed understanding of the specific export control classifications applicable to each of the US target's products. While critical technologies are defined to include the more obviously defence articles controlled under the International Traffic in Arms Regulations (ITAR), they also include a more ubiquitous range of dual-use items subject to certain export controls under the Export Administration Regulations (EAR).

Even without a mandatory filing obligation, however, M&A participants often decide to submit a transaction for CFIUS review voluntarily to obtain CFIUS approval, which includes a safe harbour from future adverse action from CFIUS and the President. If parties to a transaction subject to CFIUS' jurisdiction decide not to file voluntarily, CFIUS forever retains the authority to initiate a review and take remedial action to address any perceived national security risks (e.g., impose onerous mitigation measures or recommend a post-close divestment order from the President). DOE also is a key member of CFIUS that is actively reviewing M&A activity in the energy sector that has not been previously submitted for a voluntary review.

While protecting critical technologies remains a key focus, CFIUS also remains committed to identifying concerns posed by foreign investment in US target companies that are in close proximity to sensitive US government facilities and military training bases. This, combined with CFIUS' recently expanded jurisdiction to review certain real estate transactions by foreign persons, poses unique challenges to M&A activity in the energy sector that involve large parcels of land (e.g., mining, exploration, and solar and wind farms). Further, addressing these types of concerns has broad bipartisan support, which is unlikely to recede even with a change in the executive administration of CFIUS. M&A participants in the energy industry must account for this heightened and expanded scrutiny from CFIUS, as it affects all aspects of deal-making from buy and sell-side due diligence to deal timing and closing certainty more generally.


Despite experiencing a decline compared to past years, 2019 finished as a strong year in the leveraged loan market generally.10 This positive trend continued in the first quarter of 2020, but the US lending market came to a complete halt in March 2020 because of the covid-19 pandemic,11 with M&A lending being no exception.12 There was no new institutional loan issuance in March 2020.13 Although new issuance started again in April 2020 ($16.18 billion new issuances in the United States),14 total leveraged loan issuances in the second quarter of 2020 were still down roughly 58 per cent from the first quarter.15 M&A loan issuance, however, fared better: down in the second quarter roughly 34 per cent compared to the first.16

In addition to halting the US lending market, the covid-19 pandemic also caused an unprecedented drop in demand for oil that resulted in a crash of crude prices.17 Despite a modest rebound in crude prices, the outlook for oil demand is pessimistic and investors remain unenthusiastic about major oil and gas companies.18 Private infrastructure investment stands in contrast, however. Such investments likely will show resilience in the face of the covid-19 pandemic and will only continue to grow in the future. In particular, renewable energy sources will be a large focus of infrastructure investment.19

Such renewable investments could involve infrastructure funds investing more long-term capital through a buy-and-hold strategy or by providing back leverage, which can provide proceeds for distributions or reinvestment in new projects without a loss of ownership or control. Optimising and innovating the financing structures will continue to be a major challenge. The legal technology underlying some of the debt investments in infrastructure assets remains antiquated and needs to be updated, such as by incorporating elements of leveraged finance to provide additional flexibility. Great progress has been made by sponsor counsel already, but the trend should continue.

Due diligence

i Overview

In connection with acquisitions of energy assets, there are various due diligence work streams that must be completed, including financial due diligence, operations due diligence and legal due diligence. Although these work streams often overlap and require interaction among various specialists, this chapter focuses on the requirements of legal due diligence. Under the rubric of legal due diligence, both in-house and outside legal counsel and other advisers analyse some or all of the target assets and applicable contracts to determine compliance with laws and regulations, legal title to the assets, required consents to consummate the transaction and compliance with other legal requirements (including contract terms).

Key components of the legal due diligence process for upstream transactions are reviewing title to oil and gas properties (whether in fee or in leasehold interests) and conducting appropriate environmental diligence, as described further in subsection ii. Asset-level M&A agreements typically contain defect provisions for both title and environmental diligence, where the purchase price can be adjusted for amounts related to defects in those areas. In addition to title and environmental diligence, it is also important to review drilling contracts (as they can carry multi-year commitments at significant cost), midstream contracts (including whether the upstream company is required to deliver minimum volumes or make minimum payments to the midstream company) and saltwater disposal arrangements. Permitting and general regulatory diligence is also imperative.

A key component of the legal due diligence process for midstream transactions is reviewing key commercial agreements (such as gathering, processing, transportation and capacity agreements) associated with the assets. These agreements are particularly important to review given that they in large part determine the value of the midstream assets (and, in some instances, the associated upstream assets) and are generally long-term arrangements. Because so much of the asset value depends on the fees paid under these agreements, it is imperative that the purchaser carefully review the agreements prior to executing the acquisition agreement. The purchaser should also evaluate the creditworthiness of the applicable upstream counterparties to obtain relative comfort surrounding any long-term dedications.

Unlike many other agreements in the oil and gas space, one initial point of emphasis when reviewing a gathering, processing or fractionation agreement is that there is no standard form. Indeed, midstream agreements are typically the subject of significant negotiation between the parties and are limited only by the collective imagination of the negotiating parties.

Key components of the legal due diligence process for power and utilities transactions are reviewing revenue-generating contracts (such as power purchase agreements), other key commercial and project agreements (such as interconnection agreements, engineering, procurement and construction agreements, operating and maintenance agreements, and hedging agreements), site documents (particularly for wind and commercial solar assets but also for conventional power assets) and permits, as well as conducting appropriate environmental diligence, as described further in subsection ii.

ii Environmental due diligence

Environmental due diligence for energy M&A transactions varies by market sector and segment, transaction type and the risk tolerance of the parties involved, and depends largely on the scope and timing of the due diligence process overall. A standard environmental due diligence review includes:

  1. submission of diligence requests;
  2. review of documents provided by a target company, securities filings (for public companies), and environmental permit transfer and change-of-control requirements (for asset transactions);
  3. searches of public environmental databases and news and litigation sources;
  4. interviews with company environmental personnel;
  5. analysis of the relevant environmental regulatory framework impacting the target company's operations and anticipated changes to the same; and
  6. preparation of a due diligence summary or other work product.

In many instances, an environmental consultant is retained to conduct a technical environmental due diligence review. Depending on access to a company's facility and personnel and the factors noted above, the technical review can include site visits (e.g., Phase I environmental site assessments) or consist solely of a 'desktop' (i.e., review of written and spoken records only) review.

Certain specific considerations for environmental due diligence in energy M&A are outlined below.

Oil and gas

Environmental due diligence in upstream oil and gas transactions traditionally involves a defect process, whereby access to the assets is granted for a period of time between signing and closing to identify environmental defects, which are then addressed pursuant to the negotiated terms of the agreement (e.g., the seller remediates the defect, the purchase price is reduced by the cost to remediate the defect, the asset impacted by the defect is excluded from the transaction or the seller indemnifies the buyer for the defect). The buyer typically retains an environmental consultant with oil and gas expertise to visit all or a subset of assets during the review period to identify and value environmental defects. This review is often limited by the agreement to visual inspections of the assets (i.e., no Phase II environmental site assessments or other subsurface sampling or testing), but the buyer often has the right to exclude properties if a Phase II is warranted and consent is not granted from the seller. If the consultant identifies an environmental defect, the buyer or its counsel will work with the consultant to prepare a defect notice for submission to the seller. The parties will then negotiate a remedy to address the defect.

Power and utilities

M&A transactions in the power and utilities sector often involve complex environmental issues. Key focus areas for operating assets include allocation of emission credits and other environmental attributes, environmental obligations under consent decrees with regulators, environmental and toxic tort legacy liabilities, planned or anticipated capital expenditures (e.g., for pollution control equipment) and impacts of evolving environmental regulations. The environmental due diligence process typically follows the standard review described above, including retention of an environmental consultant. Key focus areas for development assets include environmental permitting, a National Environmental Policy Act (NEPA, or state equivalent) review of projects on public lands, lender liability protections for environmental conditions at the project site, access to water supply and waste disposal services, and third-party project challenges to the project (such as appeals of issued environmental permits). Assistance of local counsel in the jurisdiction where the project is located is often crucial. In most instances, rather than retaining its own consultants, the lender in any planned project financing will require and rely on independent engineer and environmental reports prepared by the borrower's consultants in connection with the financing.

ESG and Climate Resiliency Review

Due, in part, to increasing interest in sustainable investment by investors, regulators and other stakeholders, more M&A practitioners are considering ESG factors, including projected climate-related risks, as part of their due diligence processes. Whether led by counsel or a third-party consultant, key components of managing an ESG due diligence review include understanding the drivers of the review, identifying the key ESG topics most likely to be material to the transaction, developing an appropriate scope and work product, and integrating the review into other due diligence work streams. In addition, certain parties are conducting diligence on assets that may be exposed to physical climate risks, such as wildfires, hurricanes, flooding, and extreme heat. Such reviews are typically conducted with the assistance of a third-party consultant.

Purchase agreements and documentation

Recent developments affect the way parties in the US conclude purchase agreements and draft documentation.

i Oil and gas

In the negotiation of a typical upstream oil and gas purchase and sale agreement (PSA), the title and environmental defect mechanics are among the most intensely negotiated provisions because the value being transferred is derived from the value of the oil and gas reserves (assuming no environmental contamination) and the reserves yet to be produced. While the variations of a title and environmental defect mechanic are virtually unlimited, and such provisions must take into account the negotiating posture, size and complexity of the deal, upstream counterparties have developed a market for defects that takes into account the seller's desire to complete the deal with minimal ongoing title liability and the purchaser's desire to have meaningful rights in the event that a title or environmental issue is identified and quantified.

A seller typically provides limited title and environmental documentation before the signing of a PSA. It is customary for most diligence to be conducted during the interim period; however, once the parties have moved into the interim period, the seller will be required to provide copies of all title documentation in its possession, including any previously commissioned title opinions and landmen run sheets, and provide access to the properties to conduct a customary Phase I review.

The purchaser's protections for title issues (other than a special warranty of title included in the assignment or deed) and environmental issues are typically limited to a defect process with notice provided to the seller a certain number of days prior to closing. Under this construct, the purchaser has the ability to access and verify title to the assets and the environmental status of the assets during the period between the signing and closing of the PSA. Subject to agreed limitations, including specified thresholds and deductibles, the purchaser is entitled to a downward purchase price adjustment for identified defects affecting the assets. Once the defect claim period expires, the seller typically provides no ongoing warranties related to title or environmental issues (other than the special warranty of title).

Outside of the title and environmental construct identified above, PSAs typically include a suite of non-fundamental representations and warranties related to the status of the assets. A seller's representations 'package' is usually heavily negotiated, including exceptions and limitations on the representations, knowledge qualifiers and survival. Typical representations include:

  1. pending or threatened litigation;
  2. unwaived third-party rights;
  3. material contracts;
  4. outstanding authorisation for expenditure commitments;
  5. wells and equipment;
  6. known title and environmental issues;
  7. taxes;
  8. correct payment of royalties;
  9. suspense amounts or imbalance;
  10. compliance with laws;
  11. no previous transfers of interests outside the target depth or depths;
  12. accuracy of lease operating statements; and
  13. no material adverse effects (MAEs).

A buyer will typically have the right to terminate a PSA in the event the seller materially breaches a representation or warranty as of the closing, but the actual 'bring down' standard is often heavily negotiated (e.g., MAE, material breach, etc.). In addition, to the extent the representations survive the closing, a breach may give rise to a cause of action for damages.

In addition to asset-level representations and warranties, a PSA typically provides for indemnity for certain retained obligations, which unlike representations and warranties is not typically subject to thresholds, deductibles and caps. Although the scope of retained obligations is heavily negotiated, in most recent deals, buyers were able to require that a seller retain liabilities associated with known environmental matters and offsite waste disposal, mispayment of royalties prior to the effective time, specified litigation, taxes and excluded assets.

ii Power and utilities

Understanding the regulatory landscape

Antitrust regulatory considerations under the HSR Act are relevant to acquisitions and divestures in the power and utilities sector, as discussed in Section VIII. However, the nature of power and utilities assets poses additional regulatory complexities that are critical to assessing deal execution risk and closing certainty.

Due to the regulated natured of power and utility assets, additional regulatory approvals from FERC and state public utility commissions can impose conditions and commitments on prospective owners of these assets. The level of effort required of parties to obtain these additional regulatory approvals (and the limitations on such effort) and the consequences for the termination of transactions because of a failure to obtain these regulatory approvals can vary greatly across transactions. To mitigate the risk of regulatory failures, M&A purchase agreements will often include a broader scope of representations and warranties covering regulatory matters, such as the regulatory status of the seller and target and the absence of any regulatory impediments with respect to the buyer's ability to consummate a transaction, specific interim covenants relating to actions that would prevent or materially delay the ability of the parties to obtain regulatory approvals, and termination fees tied to failures to obtain necessary regulatory approvals.

Risk of loss and casualty and condemnation provisions

Much like industry-agnostic M&A agreements, enhanced closing certainty is a key consideration for parties in power and utility transactions, but to preserve value, buyers will often seek risk of loss provisions addressing casualty and condemnation in their transactions: these continue to be heavily negotiated as they diminish closing certainty for sellers. Risk of loss and casualty and condemnation provisions allocate the risk of loss to operating facilities as between the seller and the buyer during the interim period of a transaction: they generally seek to protect the buyer from loss of the value derived from uninterrupted operation of target facilities. While these provisions can take a variety of forms, they generally provide a remedy for buyers in the event of a casualty or condemnation event resulting in some pre-agreed amount of damage to or loss in value of the target facilities, and a termination right allowing either the buyer or the seller to terminate the transaction should such damage or loss in value exceed a material percentage that would likely fall short of constituting a material adverse effect as construed in Delaware.

Value considerations

Both sellers and buyers in all M&A purchase agreements will seek to include provisions to maximise and preserve value in their transactions: the most common provisions tend to relate to purchase price adjustment mechanics or the covenants that bind the seller during the interim period.

In power and utilities M&A transactions involving private targets, sellers will often include purchase price adjustments for items that are specific to power and utility assets such as capital expenditures, spare parts and fuel inventory, which complement the more generic adjustments for working capital, indebtedness and cash. Buyers will seek to either eliminate these additional adjustments or limit their applicability by negotiating target amounts or introducing caps.

Additionally, power and utilities buyers have been increasing their use of 'modified' locked box constructs to adjust the purchase price in their M&A agreements. A traditional locked box purchase price adjustment fixes the price at the time of execution of the acquisition agreement based on historical (usually the last audited) balance sheet accounts: the buyer, therefore, takes on the economic risks and benefits of the target during the period between signing and closing of the transaction. In a modified locked box construct, these same principles apply, but the price is instead fixed at some later-agreed date, typically representative of the valuation date underlying the buyer's model of the target, and which may follow the execution date of the acquisition agreement. Buyers are increasing their use of modified locked box constructs to ensure an alignment of purchase price and their modelling assumptions, including assumptions regarding seasonal outputs, upcoming major maintenance and other similar external factors.

Buyers will similarly attempt to maintain value in power and utility M&A transactions by imposing additional tailored covenants on sellers during the interim period. Examples of these interim period covenants include requiring the seller to spend capital expenditures in accordance with an interim period budget (if ultimately agreeable, the seller will want to ensure that this aligns with a budget it previously represented during diligence) and implementing a specific hedging programme designed to secure the economic assumptions on which the buyer based its financial model prior to actually owning the target assets. Deal teams should involve HSR counsel in drafting specific language for these provisions to ensure that the parties do not run afoul of gun jumping rules; there is less risk of gun jumping the more the covenants are consistent with the seller's historic ordinary course of operations of the target assets.

iii Representation and warranty insurance to reduce transaction risk

Dealmakers in the power and utilities and oil and gas sectors are keen to reduce transaction risk as much as industry-agnostic dealmakers and are continuing to avail themselves of a trend that has become more prevalent in M&A agreements generally across all industries and sectors in recent years: representation and warranty insurance (RWI) and other M&A insurance products. As described in more detail in Section IX, more M&A practitioners in the power and utilities and oil and gas sectors are turning to these insurance products to help eliminate transaction risk.

Key regulatory issues

i Competition

All M&A transactions, including energy transactions, are subject to antitrust laws prohibiting mergers that may substantially lessen competition. For most deals valued at more than US$94 million,20 the HSR Act requires parties to submit pre-merger filings to the Department of Justice and the Federal Trade Commission and observe a pre-closing waiting period.21 The waiting period allows the DOJ and FTC to assess the likely competitive effects of the deal and decide whether an extended investigation, or eventually a challenge on antitrust grounds, is warranted. Until the waiting period has expired, the parties must continue to compete independently and refrain from integrating any of their operations or otherwise behaving as though the merger has been completed (which, when done prematurely, is known as 'gun-jumping'). The rules governing exactly which transactions require an HSR filing are complicated and fact-specific; for instance, certain exemptions apply to the acquisition of some types of upstream carbon-based mineral assets. The HSR waiting period rules apply equally to all reportable deals, regardless of whether they present substantive antitrust concerns.

To determine whether a potential transaction is likely to harm competition, the reviewing agency considers numerous case-specific factors. The agencies often begin by defining relevant product and geographic markets, identifying participants in those markets, and analysing how the proposed transaction would affect competition in each relevant market. The agencies will oppose a deal if they conclude (after an extensive investigation) that it may substantially lessen competition and thereby lead to higher prices or reduced quality, innovation, or output. When the agencies oppose a deal, the parties may enter into a negotiated settlement with the agency to remedy the perceived potential for harm to competition. Such settlements typically require the divestiture of assets, although occasionally they may be limited to restrictions on the post-closing conduct of the merged firm (such as the imposition of information firewalls or assurances of continued supply to a competitor of one of the parties). Parties also may terminate or restructure proposed transactions in the face of agency concerns. In the small minority of cases in which agency opposition to a deal does not lead to a negotiated settlement, termination, or restructuring, the agency may attempt to block the deal by seeking an injunction in court.

While both the DOJ and FTC have the statutory authority to investigate mergers, only one agency or the other may proceed to investigate any particular deal. Historically, the FTC has reviewed oil and gas deals and coal transactions, while the DOJ has focused on oilfield services and power generation. State attorneys general also occasionally investigate mergers, either in concert with or independently of the DOJ and FTC.

The FTC has explained that pure upstream deals are unlikely to be anticompetitive because individual companies hold small shares of global crude oil reserves and production. However, upstream deals are not immune from antitrust scrutiny, as evidenced by the 2000 merger of BP Amoco and ARCO, then the two leading producers on the North Slope of Alaska. Along with various downstream theories of harm, the FTC alleged that the deal would reduce competition in the purchase of exploration leases from the State of Alaska and in the sale of North Slope oil to certain refiners that could not readily shift to other sources of supply. This matter, which attained antitrust clearance through a divestiture of assets, underscores the fact that the agencies assess each deal on its own merits.

In the midstream sector, the FTC defines product markets by focusing on a specific petroleum product transported, refined or stored in a particular way. The FTC has required remedies when customers for a particular product in a particular region would be left with few competitive options. For example, the FTC objected to the proposed 2016 merger of Energy Transfer Equity (ETE) and the Williams Companies (which was later terminated for non-antitrust reasons) because the merged firm would have owned or controlled two of the three interstate pipelines providing firm transportation of natural gas to a certain part of the state of Florida. The parties agreed to resolve the FTC's concerns through an asset divestiture, and (regarding a vertical supply-related issue) post-closing conduct requirements. Similarly, in connection with the 2015 combination of Par Petroleum with Mid Pac Petroleum, which were two of the four firms supplying Hawaii with bulk quantities of Hawaii-grade gasoline blendstock, the FTC required Par to terminate Mid Pac's storage and throughput rights at an import terminal, which it could have used to impair another importer's ability to compete effectively. Finally, the agencies may take issue with non-controlling acquisitions, as demonstrated by the FTC's objection in 2007 to a proposed minority investment in Kinder Morgan by investors that also held a 50 per cent interest in Magellan Midstream, which competed with various Kinder Morgan terminaling operations.22 The investors obtained FTC approval for the proposed investment without a divestiture of assets by agreeing to erect information firewalls between the companies (ensuring no competitively sensitive information would be exchanged) and not to appoint board members to Magellan Midstream (ensuring they could not direct it to compete less vigorously).

Further downstream, the FTC regularly requires divestitures of select gas stations in mergers of gasoline retailers that would leave few independent competitors in narrow local areas. Recent examples include Tri Star Energy/Hollingsworth Oil (2020) (in which the parties divested only two gas stations, demonstrating the FTC's readiness to act against deals with even a small anticompetitive impact), Express Mart/Speedway (2019) and Alimentation Couche-Tard/Holiday Companies (2018). The FTC also fined Couche-Tard US$3.5 million in 2020 for violating the settlement by failing to timely divest the gas stations, maintain their viability pre-sale, and provide accurate information about its efforts to comply with the settlement.

In the coal sector, in 2020 the FTC sued to block a proposed joint venture combining certain thermal coal operations of Arch Coal and Peabody Energy, alleging that it would lessen competition in the sale of coal mined in one particular region (the Southern Powder River Basin), which is characterised by certain unique properties. The court found that such coal was a relevant market, rejecting the parties' argument that the pricing power of the JV would be constrained by the availability of other types of coal to power producers as well as other types of power generation. After the court granted the FTC a preliminary injunction blocking the JV, pending a full trial on the merits, the parties abandoned the proposed transaction.

The DOJ has been active in the oilfield services segment in recent years, investigating such transactions as Ensco/Rowan (now Valaris) (offshore drilling) and Schlumberger's proposed OneStim JV with Weatherford (onshore hydraulic fracturing). The DOJ also rejected a proposed settlement in Halliburton/Baker Hughes (2016), leading to the abandonment of that transaction, and required a divestiture in the subsequent purchase of Baker Hughes by GE (2017). In the proposed Halliburton deal, the DOJ alleged that the transaction would lessen competition in 23 separate narrowly defined product and service markets, mostly relating to offshore drilling and production, such as fixed cutter drill bits, offshore directional drilling, offshore surface data logging services, cased whole wireline services for rigs in deepwater, and many more. The DOJ rejected the proposed divestiture package, claiming it would not fully and successfully replicate competition because it did not include full business units, withheld many critical assets and personnel, and involved numerous ongoing entanglements between the parties and the divestiture buyer. In the subsequent sale of Baker Hughes to GE, the DOJ alleged that the merger would combine two of the leading providers of refinery process chemicals and services and required the divestiture of the relevant GE division.

In the power sector, the DOJ's most recent merger enforcement action concerned Exelon/Constellation Energy (2011). Although the parties' combined market share in the sale of wholesale electricity would have been less than 30 per cent in the relevant region, the DOJ alleged that because of the unique competitive dynamics of the wholesale electricity market, Exelon would find it profitable to withhold output and raise prices. The DOJ cleared the deal pursuant to a settlement requiring the divestiture of three power plants. Additionally, in 2017 the DOJ sued Duke Energy in a rare standalone action for gun-jumping in connection with Duke's acquisition of a power plant. The DOJ alleged that before the parties made their HSR filings (let alone before the HSR waiting period expired), the parties entered into a tolling agreement under which Duke made competitive decisions for the plant, such that it ceased to compete independently in violation of the rules on gun-jumping. This effect of the tolling agreement allowed the parties to argue to FERC that Duke already controlled the plant, and thereby bypass an additional level of scrutiny that FERC applies to acquisitions increasing market concentration beyond a certain threshold; this apparently calculated violation of the gun-jumping rules likely contributed to the DOJ's decision to take action. Duke agreed to resolve the DOJ's lawsuit by paying a $600,000 civil penalty.

ii Environmental protection

At the federal level, the trend in recent years has been to roll back prior environmental regulations governing the energy industry. Over the course of President Trump's term, his administration has continued its efforts to narrow the scope of federal environmental regulations, including unwinding the Obama-era 'Climate Action Plan' and implementing the changes announced in President Trump's Executive Order 13783, which was aimed at eliminating regulatory requirements on domestic energy development. For example, the US Environmental Protection Agency has proposed or implemented rollbacks of federal regulations regarding methane emissions from upstream oil and gas sources, hydraulic fracturing on public lands, and carbon dioxide emissions and coal ash waste from coal-fired power plants. However, at the state level, certain states have gone against federal trends by increasing environmental protection regulations applicable to the energy industry and taking proactive action to address projected climate change impacts. Most notably on oil and gas production, Colorado Senate Bill 19-181, which was signed into law 16 April 2019, expands local government control over oil and gas development in the state, elevates environmental, health and safety considerations in permitting decisions, and alters pooling, drilling and permitting requirements to be less favourable to industry. Similarly, in California, AB 1057, signed into law in October 2019, specifies that the purposes of provisions relating to oil and gas conservation in the state include protecting public health and safety and environmental quality. Recent years have also seen expansion of greenhouse gas 'cap and trade', with states including New Jersey, Pennsylvania and Virginia taking steps to join a regional initiative to reduce greenhouse gas emissions. In addition to state action, recent court decisions have trended towards requiring federal agencies to consider climate-related risks when reviewing energy projects (e.g., interstate pipelines, oil and gas leases on public lands, electric transmission lines) under NEPA; however, in July 2020, the White House Council on Environmental Quality issued an order aimed at streamlining NEPA reviews for such projects.

iii Health & Safety

On the health and safety front, under a new Occupational Safety and Health Administration standard limiting respirable silica exposure that went into effect on 23 June 2018, the oil and gas industry must implement engineering controls and work practices to limit exposures below the new limits by 23 June 2021.

iv Tax

Oil and gas M&A transactions raise many of the same tax issues that arise in M&A in other industries. For example, tax-free, like-kind exchanges are prevalent in oil and gas transactions. Of course, there are tax issues unique to the oil and gas industry. Many of these issues relate to certain favourable oil and gas tax rules, such as the ability to take depletion deductions with respect to oil and gas properties and to deduct drilling costs in the year incurred. Oil and gas tax is a highly specialised area requiring a knowledge of both the tax rules and the industry.

The biggest tax development in recent years was the passage of the landmark Tax Cuts and Jobs Act (TCJA) in 2017. The TCJA has impacted M&A transactions, primarily through the enactment of 100 per cent expensing (bonus depreciation) for certain tangible assets. These new expensing rules apply to acquisitions of most midstream assets but have limited applicability to acquisitions of upstream oil and gas properties. The rules apply to most renewable energy assets as well, such as solar and wind assets. Used equipment is also eligible for bonus depreciation if it is acquired from an unrelated party in an arm's-length sale. Bonus depreciation is available at a 100 per cent level for qualifying tangible assets placed in service until December 2022. It then phases down by 20 per cent per year for property placed in service until 2026. Certain longer-lived tangible assets that are normally depreciated over 10 or more years, such as transmission lines, are allowed an additional year to qualify (subject to certain limitations). The TCJA also limits interest deductibility and the use of net operating loss carry forwards.

In addition, the TCJA cut the corporate tax rate from 35 to 21 per cent. This development, along with others (including a key FERC ruling), has led certain publicly traded master limited partnerships to abandon their pass-through status and convert to corporations.

v Anti-money laundering, sanctions and anti-corruption

Primary focus in this space continues to be a dynamic US sanctions landscape. US sanctions have had arguably a unique impact on the energy sector given the prevalence of state-owned energy companies in countries that have found themselves in the crosshairs of US foreign policy. For instance, the US has shown few signs of relaxing its sectoral sanctions programme targeting a number of Russian state-owned oil and gas companies. These sanctions broadly prohibit US persons from trading in certain new equity and moderate-to-long-term debt instruments of a number of Russian energy firms and their subsidiaries.

Further, US sanctions against Venezuela and its state-owned enterprises have had a continued adverse impact on the ability of its energy sector to access financial markets. One significant collateral consequence of these comprehensive sanctions against Venezuelan state entities has been to prompt US-based Citgo to cut ties from Petróleos de Venezuela, its corporate parent, in exchange for relief from US sanctions. For the time being, Citgo nominally remains a sanctioned entity, albeit subject to a general licence (renewed at least through early 2021) to permit its continued access to US counterparties and global financial markets.

The United States has shown continued willingness to impose sanctions to discourage third-party companies and vessels from offering material support to certain disfavoured regimes. For example, in late 2019, the United States targeted with comprehensive sanctions a number of Chinese tanker vessels known to have transported Iranian oil products. US sanctions pressure more recently led a Swiss-based contractor to withdraw from Russia's Nord Stream 2 pipeline project, and US legislation pending at the time of printing would expand this sanctions threat to include certain non-US insurers and underwriters acting in respect of the project.

The existence and complexity of US sanctions underscores the importance of a robust anti-money laundering and due diligence process. This review should include thorough know-your-customer diligence of transaction counterparties, as well as key contractual counterparties of acquisition targets, to identify both extant risk as well as anticipated exposure to escalating sanctions. Companies entering joint ventures and service contracts are well advised to incorporate termination provisions tied to the imposition of US sanctions instead of relying on force majeure clauses. Additionally, firms should be mindful that lenders and insurers may apply more cautious risk thresholds when considering participating in a project with sanctions risk exposure, particularly against such a dynamic backdrop.

Inherent corruption risk remains prevalent in the energy sector in much of the world, and it remains the single most prevalent industry sector for enforcement of the US Foreign Corrupt Practices Act, with several new cases announced in the past twelve months. Operational complexity, the high-stakes nature of energy and natural resources exploration grants and contracts, and the prevalence of state-owned entities and regulatory hurdles in emerging markets that inherently present a higher risk of corruption are some reasons for the corruption risk in this sector. While anti-corruption enforcement in this sector is hardly novel, what bears notice is the emergence of meaningful non-US anti-corruption enforcement in recent years. Multinational cooperation with respect to anti-corruption enforcement activity in the energy sector in Brazil, Mexico, Ecuador, Venezuela and Argentina, among other jurisdictions, underscores the dual-front nature of this risk.

vi Energy regulation

Among the most important regulatory issues in energy M&A transactions are the various prior authorisations necessary to consummate a transaction. As noted above, states take various approaches to regulating such transactions, with only some states requiring prior regulatory approval of the transaction. At the federal level, however, there are multiple regulatory agencies with authorisation requirements that could be triggered by an energy M&A transaction; those agencies include FERC, DOE, NRC, MARAD and USCG, and FCC. Accordingly, for any energy M&A transaction, detailed knowledge of the assets, and the regulatory permits and licences they hold or require, is critical to avoid closing over one or more of the necessary prior authorisation requirements that may apply.

In recent years, one of the most significant developments in the US energy sector is the increased export of natural gas, particularly as liquefied natural gas (LNG). FERC and the DOE share jurisdiction over the export and import of natural gas and LNG, with the DOE having authority over the actual import and export of the commodity and FERC having authority over the facilities used for such imports and exports. Although FERC's regulatory regime is commercially relevant to energy M&A transactions involving such infrastructure, FERC's prior approval is not necessary for such transactions, absent a change in the operations or services provided by the facilities. The DOE, however, does have rules pertaining to changes in ownership or control of facilities used for natural gas and LNG exports and imports. Depending on the nature of the transaction and whether it constitutes a change in control for the DOE's purposes, DOE approval may be required. If approval is required, the specific process for obtaining it varies depending on the terms of the individual export authorisation at issue and whether the nation to which the exports are shipped has entered into a free trade agreement with the United States. If an onshore or offshore oil or natural gas asset qualifies as a deepwater port, under the Deepwater Ports Act of 1974, it is also subject to an additional regulatory regime that is jointly administered by MARAD and USCG, in conjunction with numerous other federal and state agencies. Given the extensive nature of the overlapping federal and state regulatory regimes for deepwater ports, energy M&A transactions that involve deepwater port facilities may require multiple regulatory authorisations, including a prior authorisation from MARAD if a deepwater port licence includes a condition requiring such authorisation prior to a change in ownership.

The federal regulatory requirements most often relevant to transactions involving power and utilities are those administered by FERC, pursuant to Section 203 of the Federal Power Act, which requires public utilities to obtain FERC's prior authorisation for certain types of transactions. As relevant to power and utility M&A, that statutory provision requires prior approval from FERC before a public utility:

  1. sells, leases or otherwise disposes of a FERC-jurisdictional transmission facility, or any part thereof, in excess of US$10 million;
  2. directly or indirectly merges or consolidates FERC-jurisdictional transmission facilities, or any part thereof, that have a value in excess of US$10 million, with the facilities of any other person; or
  3. purchases, leases, or otherwise acquires an existing generation facility that has a value in excess of US$10 million and is used for interstate wholesale sales over which FERC has rate-making jurisdiction.

In energy M&A transactions involving power generation assets, the characteristics of the generation asset, the identity of its owner, and the nature of its commercial arrangements all may be relevant to whether FERC's prior authorisation under Section 203 of the Federal Power Act is required. For example, renewable energy generation facilities with certain characteristics may qualify for an exemption under the Public Utility Regulatory Policies Act (PURPA). In one of the more significant developments in the power sector in 2020, FERC overhauled its regulations implementing PURPA, which has created some uncertainty regarding the regulatory status of such facilities and has caused companies that own, or are considering acquiring, such facilities to exercise heightened diligence in assessing associated regulatory requirements.

In addition to the FERC requirements, energy M&A transactions can also necessitate prior authorisation from other federal agencies for the transfer of certain permits or licences. For example, M&A transactions involving radioactive materials implicate federal regulatory requirements administered by the NRC. In particular, under Section 184 of the Atomic Energy Act and the NRC's implementing regulations, the licence for a nuclear generation facility, and any right under such a licence, may not be 'transferred, assigned, or in any manner disposed of, voluntarily or involuntarily, directly or indirectly, through transfer of control of the licence to any person, unless the NRC gives its consent in writing'. That prior authorisation requirement applies to nuclear reactors, which may be included in a power and utility sector M&A transaction, and the various devices and instruments containing radioactive material that are often used in upstream and midstream natural gas and oil operations.

Finally, any given energy M&A transaction, whether for upstream or midstream oil and natural gas assets or for power assets, may induce regulatory requirements, including prior authorisation requirements of the FCC. Companies in the oil, natural gas and power industries commonly use communications systems that are regulated by, and require licences from, the FCC. The FCC regulates changes in control of such licences, with the specific requirements varying based on the type of licence at issue. Some licences may be transferred with the FCC's prior approval, whereas other licences require the acquiring entity to apply for a new licence prior to a change in control.

The various energy regulatory regimes and prior authorisations discussed above follow different procedural rules and timelines, many of which are measured in months rather than days or weeks. It is imperative that the energy regulatory requirements associated with an energy M&A transaction be identified and built into a deal timeline in the early stages of a transaction.


Faced with macro-economic uncertainty resulting in large part because of depressed commodity prices and the ongoing covid-19 pandemic, energy M&A practitioners, much like those that are industry agnostic, are increasing their use of insurance products to manage R&W, tax and litigation transaction risk in an effort to maximise sale proceeds for sellers and affording buyers comfort in pursuing opportunities in a difficult deal environment.

Insurance for R&W and tax has becoming more prevalent in energy M&A transactions as the cost of insurance policies continues to decline and broader coverage terms, particularly with respect to tax matters, offer more comprehensive coverage for buyers. Additionally, with the covid-19 pandemic continuing to cause distress in the certain subsectors of the energy sector, buyers are becoming more reliant on insurance policies in M&A transactions where health and safety presents a heightened litigation risk or there is the possibility of contingent liabilities (e.g., creditor claims) as the transaction involves a target that is in financial distress or insolvent.

The covid-19 pandemic is also shaping how insurance providers in M&A transactions are approaching policy terms and underwriting insurance. Underwriters have varied their approach to covid-19 generally, with some underwriters insisting on broad exclusions of all losses resulting from covid-19 while others taking a more tailored approach driven by a variety of factors such as the industry in which the target operates. Additionally, because the nature of buyer due diligence and seller disclosure is fundamental to underwriting M&A insurance products, underwriters have expanded their scope of due diligence in 2020 to cover the impacts of the covid-19 pandemic. That being said, insurance providers have adapted their due diligence processes and insurance coverage terms to address access issues faced by buyers and their advisers in an environment that has been complicated by the covid-19 pandemic. If a buyer is unable to diligence a specific matter relating to the target because of health considerations implicated by covid-19, insurance underwriters have, for example, provided for conditional exclusions, in effect postponing effectiveness of coverage for the matter until sufficient diligence is completed.

Insurance providers for M&A transactions are also becoming more sophisticated in their approach to underwriting environmental risk, although for industrial targets, such as those in the energy space, many providers will cover contamination-related risks only in excess of an underlying pollution legal liability (PLL) insurance policy. While several European insurers have recently implemented restrictions on underwriting in the coal industry, PLL coverage, including coverage for existing contamination, continues to be available for coal industry targets from certain US carriers. Pairing a PLL policy with a RWI policy, for example, can facilitate no indemnity deals even for the types of complex environmental risks often attendant in the energy space.

Dispute resolution

Energy deals are susceptible to the same type of litigation seen in M&A transactions across all industries. Litigation following an M&A transaction is frequent, and almost inevitable in the case of mergers involving publicly traded companies. While litigation is common, there are several measures M&A parties can take to mitigate risk and avoid inefficient and protracted litigation. Below is a description of some of the most frequent types of M&A-related claims and causes of action, and some of the provisions in merger agreements that can have a significant impact on merger-related litigation.

Common merger-related litigation

Disclosure 'strike suits' and other shareholder suits

M&A are often subject to lawsuits raised by (usually the seller's) shareholders. This is especially prevalent with publicly traded companies. A typical form of shareholder lawsuit is a strike suit seeking an injunction of the merger to leverage a potential delay of the transaction and extract a settlement. Most often, these are premised on the seller having allegedly improper public disclosures regarding the transaction and the seller agreeing to settle to allow the transaction to go forward. In recent years, however, Delaware courts have refused to approve such settlements because they provide little value to shareholders, although strike suits continue to be filed in other state and federal courts. Although these suits are unavoidable, thorough disclosures can mitigate liability. Engaging a disclosure expert who can fashion disclosures that are sufficient and on par with those of the company's peers can help lower settlement value.

In certain jurisdictions providing for dissenting shareholders' rights, appraisal suits are filed by the target's shareholders dissatisfied with the consideration for their stock seeking to recover a premium over the purchase price. The court will determine the fair value of the shares, exclusive of any increase captured by the expectation of the merger. While deal price is sometimes considered the best evidence of fair value, courts will also consider evidence related to the merger process, including whether the transaction was arm's-length. Building a strong record during the negotiations and diligence, including minutes of board meetings, showing that the parties to the transaction bargained at arm's-length, and that the transaction was approved by disinterested directors and by a fully informed stockholder vote, can go a long way towards defeating appraisal actions.

MAE clause

Most merger agreements have a MAE clause, which allows a buyer to terminate a purchase when there has been a change (typically between execution and closing) in the target's business that is so significant as to essentially defeat the entire purpose of the transaction. While it has historically been extremely difficult for buyers to invoke MAE clauses, a recent decision in Delaware Chancery Court shows that courts are willing to enforce MAE clauses where the facts are egregious enough that the entire transaction should be set aside.23

M&A practitioners should, therefore, engage in careful drafting of MAE clauses so that they properly capture the risks their clients are willing to take.


An earnout provides a seller with additional consideration based on the performance of a business or asset following the close of a transaction. While earnout provisions help parties who cannot agree on a final transaction price, they can be the subject of litigation if the earnout provision is not drafted carefully. In a recent Delaware case, the Chancery Court found that a buyer's attempt to withhold earnout payments based on suspected fraud by the acquired company's CEO did not comply with the mechanism of the earnout provision, which required payment of the earnout to the seller once the buyer had identified the amount of the earnout.24

While the earnout provision did permit the seller to challenge the earnout and for a third-party auditor to determine the result of such a challenge, the buyer had the burden of checking its earnout numbers for any adjustments based on fraud. Parties to M&A transactions should, therefore, draft earnout provisions and their dispute resolution procedures carefully to protect their clients' respective interests in the event of a dispute.

Key terms and conditions impacting merger litigation
Governing law and forum selection clauses

Of the deal terms that can impact M&A parties' chances in litigation, clauses on governing law and forum selection rank near the top. Governing law clauses are an agreement by the parties to a merger agreement that any dispute related to the terms of that agreement will governed by the law of a specific jurisdiction. Certain jurisdictions, such as Delaware and New York, have well-developed case law interpreting customary provisions in merger agreements, which allows the parties to take some comfort about the predictability of any litigation in those jurisdictions.

Similarly, certain jurisdictions' courts are more experienced and adept at adjudicating disputes involving complicated documents like merger agreements. Again, Delaware (especially the Delaware Chancery Court) and New York (including the Commercial Division) provide reliably qualified and competent jurists who understand the mechanics of a merger agreement. In the energy space, Texas judges are also more likely to be familiar with the subject matter. Parties to M&A transactions should, therefore, think carefully about their forum selection clause to mitigate against potentially negative results.

Parties may also consider mandatory arbitration clauses. Arbitration has many benefits, including the ability to select arbitrators with expertise in the energy field, faster proceedings and confidentiality. However, arbitration can have its downsides: arbitrators' judgments are typically not appealable, arbitration is expensive as the parties pay the costs of the arbitrator, and arbitrators may be more inclined to find a middle ground even where one party clearly has the better argument.

Jury waivers

M&A are inherently complex transactions, with intricate structures, deal terms, representations and warranties, and economics. As a result, any litigation over the terms of a merger agreement is also likely to involve complicated issues. Buyers and sellers should, therefore, insist on a jury waiver clause to avoid the risk of a jury of laypeople misunderstanding the complexities of the issues at stake in the litigation. Jury waivers should be drafted carefully to expressly and irrevocably waive the parties' right to a jury trial.


Merger agreements typically contain indemnification clauses. These are generally made in favour of the buyer, and the seller agrees to indemnify the buyer for claims arising out of a breach of the sellers' representations and warranties. Indemnity clauses should, therefore, be drafted precisely to fully capture the desired range of retained liabilities. Indemnity obligations are also typically subject to certain limitations, including floors and caps on liability. Recently, indemnity caps have dropped overall because of the increasing availability of RWI. Parties to M&A transactions should consider retaining counsel specialising in RWI to properly assess the potential liabilities associated with indemnification provisions.


i Oil and gas

Practitioners are cautiously optimistic about 2021. There remain significant headwinds to accelerated M&A activity because of the overall macroeconomic environment together with: bearish investor sentiment because of excess supply concerns and demand concerns resulting from the global pandemic; geopolitical issues, particularly those involving China and the new Democratic administration in the United States; negative associations about ESG issues at oil and gas companies; significant concerns about the amount and serviceability of indebtedness at many oil and gas companies; concerns about the ability to generate free cash flow for return to shareholders; and expectations of lower growth capital expenditures.

While strategic deals may still get done at low or no premium of an unaffected stock price immediately prior to announcement, large premium strategic transactions will likely be relatively rare in 2021. Asset level deals will probably continue to remain subdued until commodity prices improve, particularly if additional regulation is adopted to limit the use of hydraulic fracking technology in the extraction of oil and natural gas. State concerns stem from similar issues around hydraulic fracking, but additional issues also relate to drilling setbacks and disposal wells.

The equity and debt capital markets likely will remain challenging for most oil and gas companies, with the exception of those companies with the best credit profile. Investors are looking for low levels of indebtedness, the visibility of free cash flow generation, and a return of capital through share repurchases or dividends. Many oil and gas companies will continue to be unable to satisfy investors' concerns in these areas. Private equity companies will probably continue to serve as a source of alternative financing through the use of innovative deal structures. Nevertheless, the oil and gas industry will remain challenged in 2021, and there is likely to be continued restructuring activity among the more highly levered companies.

ii Power and utilities

Dealmakers in the US power and utilities sector are generally optimistic that M&A activity in the sector relative to other sectors will increase in the next year despite continued uncertainty resulting from the covid-19 pandemic. The positive outlook expressed by power and utilities industry participants is likely attributable to the nature of their businesses – they deploy significant time and resources to maintaining operations in the ordinary course despite emergencies, crises and other unplanned events, putting them in a better position relative to companies and businesses in other sectors to respond to the circumstances resulting from the covid-19 pandemic. In addition, the broader transition toward a decarbonised economy is expected to continue to contribute to resilience in the sector in 2021 and beyond. Meanwhile, the abundance of energy transition SPACs coming out of 2020 will undoubtedly contribute to M&A activity in the coming year as these companies identify targets for their de-SPAC mergers.


1 Sean T Wheeler, Kristin Mendoza, Roald Nashi and Robert Fleishman are partners at Kirkland & Ellis LLP. The authors would like to thank the following lawyers at Kirkland who contributed to this report: Brooksany Barrowes, Chuck Boyars, Scott Cockerham, Shawn Cooley, James Dolphin, Jonathan Fombonne, Nicholas Gladd, Cassidy Hall, Christopher Heasley, Ian John, Jonathan Kidwell, Charles Harold Martin, Nick Niles, Anna Rotman, Ahmed Sidik, Chad Michael Smith, Paul Tanaka, Evan Turnage and David Wheat.

2 'Power and utilities deals insights: Midyear 2020', PwC,

3 ibid.; see also 'US power sector M&A activity quiets down in Q2'20', S&P Global Market Intelligence,

4 'Power and utilities deals insights: Midyear 2020', PwC,

5 ibid. 'Brookfield Renewable Receives Approval to Merge with Terraform Power and Confirms Date to Distribute Shares of Brookfield Renewable Corporation', Brookfield Renewable Partners LP, The 38.5 per cent stake of TerraForm Power, Inc represents the remaining shares of the target not owned by Brookfield.

6 '2020 Preqin Global Infrastructure Report', Preqin Ltd.

7 'Power and utilities deals insights: Midyear 2020', PwC,

9 'The Biden Plan to Build a Modern, Sustainable Infrastructure and an Equitable Clean Energy Future',

10 'What's Market: 2019 Year-End Trends in Large Cap and Middle Market Loan Terms', Practical Law Finance (28 Feb 2020),

11 'LCD Global LoanStats', S&P Global Market Intelligence (11 May 2020).

12 'What's Market: 2020 Mid-Year Trends in Large Cap and Middle Market Loans', Practical Law Finance (22 July 2020),

13 'LCD Global LoanStats', S&P Global Market Intelligence (11 May 2020).

14 ibid.

15 'What's Market: 2020 Mid-Year Trends in Large Cap and Middle Market Loans', Practical Law Finance (22 July 2020).

16 ibid.

17 Matt Egan, 'Oil crashes to fresh 18-year low as demand suffers unprecedented drop', CNN (30 March 2020),

18 See Christopher M Matthews and Sarah McFarlane, 'Pandemic Pain Persists for Big Oil Companies', Wall Street Journal (1 October 2020),

19 For example, at ibid.

20 The threshold is adjusted annually. It was set at US$94 million in February 2020 and will be adjusted again in February 2021.

21 The initial statutory waiting period is 30 days. It may be extended significantly in the event of an in-depth agency investigation or terminated early by the DOJ and FTC at the request of the merging parties if the agencies are satisfied that the deal does not present competition concerns.

22 The ETE/Williams matter referenced above also concerned a combination of non-controlling interests, though in that case, the parties each held 50 per cent of the relevant assets, whereas in Kinder Morgan, the parties held 50 per cent of one asset and proposed to buy a minority of the other asset.

23 Akorn, Inc v. Fresenius KABI AG, CA No. 2018-0300-JTL, 2018 WL 4719347, *62, (Del Ch, 1 October 2018), aff'd, 198 A.3d 724 (Table) (Del 2018).

24 GreenStar IH Rep, LLC v. Tutor Perini Corp, CA No. 12885–VCS, 2017 WL 5035567, *7 (Del Ch, 31 October 2017), aff'd, 186 A.3d 799 (Table) (Del 2018).

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