The U.S. natural gas market is experiencing an unprecedented transformation. With the technological advancements in shale exploration, combined with increasing exports of natural gas, natural gas liquids (“NGL”) and liquified natural gas (“LNG”), the volumes of natural gas traded in the physical and financial markets are significantly increasing. LNG expansion is increasing the global participation in the U.S. natural gas markets, including the number of market participants with different financial and operational capabilities. This, in turn, is increasing the importance of properly identifying, quantifying, and managing the legal, regulatory, operational, and financial risk associated with natural gas marketing.
The NAESB master agreement for purchase and sale of natural gas and NGL is the most frequently used umbrella agreement in the natural gas industry. Market participants across the natural gas marketing chain such as natural gas producers, gathering and processing companies, pipelines, power and gas utilities, and various commercial and industrial end users rely on the NAESB to memorialize their purchases, sales, and exchanges of natural gas and NGLs. In order to properly manage exposures using the NAESB master agreement, market participants need to understand the relevant legal, credit, and operational aspects of the natural gas business.
I am pleased to announce that I will be conducting an in-depth and practical analysis of the NAESB master agreement, overview of the most critical special provisions, transaction confirmations, and credit support issues relevant to successfully drafting and negotiating NAESB documentation on October 4-5, 2018 in Houston.
At the request of several attendees at the upcoming ISDA seminar, the seminar agenda has been expanded to include an in-depth look at the mandatory margin requirements for uncleared swaps and its effect on various market participants. Dodd-Frank’s swap margin rule requirements became applicable for “financial end-users” on March 1, 2017. However, there appears to be a considerable amount of confusion among market participants about which type of entities are included in the definition of “financial end-user.” In order to address this issue, the seminar will examine the statutory definition of the term financial end-user and some practical steps that market participants can apply in determining their status under the rule. Also, the seminar will include the differences between the terms “hedging entity” and “financial end-user” due to some uncertainty about the impact of each designation on the margin rule implementation.
Many end-users including energy companies, commodity producers, transporters, and marketers have been receiving numerous self-disclosure letters from swap dealers and major swap participants requesting certain identifying information, even though those end-users may not be considered “financial end-users.” The seminar will examine the scope of the margin rule’s impact on the non-financial end-users and what exactly they are required to comply with under the margin rule. In addition, the practical implementation of any margin rule requirements is very likely to impact the underlying swap documentation including any credit support documentation. The seminar will examine some practical steps that can assist market participants in the most efficient way for amending existing documentation in order to comply with the margin rule.
The margin rule’s requirements are likely to increase the cost of OTC (uncleared) derivatives. One of the most pressing challenges for all market participants is the impact of this increased transactional cost on their hedging ability. All end-users, whether financial or non-financial, may have to re-evaluate the availability of hedging opportunities due to market liquidity fluctuations and the cost fluctuation associated with their particular hedging strategies. The hedging headwinds may also be amplified by the potential for regulatory arbitrage as United States regulators, including the CFTC and the Prudential Regulators (OCC, FRB, FDIC, FCA, and FHFA), are expected to significantly modify the Dodd-Frank rules while the European, Asian, Canadian, and Australian regulators are expected to continue their regulatory requirements unchanged, at least for now. The seminar will examine some practical implications of this regulatory arbitrage.
The seminar agenda can be found at the following link: http://kolobaralaw.com/client_alerts.html
In recent years, participants in over-the-counter (“OTC”) derivatives markets have experienced an unprecedented regulatory burden. Because of Dodd-Frank, EMIR and similar regulations, the documentation for OTC derivatives is becoming increasingly complex and risky. Many companies are uncertain about their ability to hedge due to regulatory and financial risk associated with derivatives documentation. In order to facilitate an in-depth analysis of the OTC documentation drafting, analysis, and review, I will be conducting a two-day ISDA® seminar on April 5-6, 2017, in Omaha, NE
This seminar is intended to help attendees better understand the key provisions of the ISDA® Master Agreement, Credit Support Annex and various Schedules. In addition, attendees will learn the most relevant and recent regulatory developments regarding mandatory margin requirements, position limits, collateral management, and reporting requirements.
Some of the topics to be covered during this seminar will be:
- Architecture of ISDA® Documentation
- 1992 and 2002 Master Agreements
- 1994 Credit Support Annex
- Schedules to the master agreement and credit support annex, natural gas and power annex, crude oil annex, long form confirmation.
- Various confirmation provisions for interest rate, credit default, and FX swaps.
- Comprehensive overview of events of defaults, remedies, cross-affiliate and cross-products netting and setoff.
- Bankruptcy and liquidation considerations.
- Special considerations regarding swap reporting and recordkeeping under Dodd-Frank.
- ISDA® August 2012 and March 2013 Dodd-Frank Protocols.
- EMIR provisions applicabe to the U.S. market participants.
For more information about this seminar please contact Kolobara Law Firm by email at email@example.com or by phone at 402-881-3987.
On March 8, 2016, U.S. Bankruptcy Court Judge Shelley C. Chapman permitted Sabine Oil & Gas (“Sabine”) to reject its gathering agreements with two pipeline operators as “executory contracts.” Although the Court’s decision is non-binding as to the underlying issue of the whether the contracts created a property interest in the underlying mineral estate, the ruling could nevertheless create a chilling effect on industry-typical practices regarding such agreements. Prior to this decision, pipeline operators (and the banks providing them financing for building the gathering and processing facilities) have believed that a well-drafted gathering and processing contract for certain minimum delivery obligations would survive a driller’s bankruptcy.
Before filing for bankruptcy, Sabine had entered into gathering contracts with pipeline operators where Sabine agreed to dedicate all oil and gas from certain designated areas, subject to specified minimum volume or payment requirements, to the pipeline operators. The agreements, governed by Texas law, specifically provide that the agreements themselves create a “covenant running with the land.” After filing for Chapter 11 protection in the Southern District of New York, Sabine filed a motion to reject the gathering agreements under the Bankruptcy Code as unduly burdensome “executory contracts.” The pipeline operators objected, arguing that the gathering agreements are covenants that run with the land and, therefore, cannot be rejected in bankruptcy. If the agreements are, in fact, covenants that run with the land, they would not be subject to rejection in bankruptcy.
The legal issue before the Court, then, was whether the gathering agreements are executory contracts subject to rejection in bankruptcy (thus creating a breach of contract and putting the pipeline operators in the category of general unsecured creditors), or if the agreements create a property interest that attaches to the mineral estate and continues with the land, unaffected by the bankruptcy.
The Court did not resolve the property interest issue in its ruling. Rather, the Court decided that Sabine satisfied the “reasonable business judgment” standard that is applied in determining whether executory contracts have been properly accepted or rejected by the debtor. For procedural reasons (the issue was before the Court on a Motion to Reject rather than an adversarial proceeding or contested matter, and the Court found that a substantive legal ruling must occur in the context of one of the latter), the Court explained that it’s decision was non-binding. However, it left no doubt as to what the final, binding determination would be if properly brought before the Court:
If it is ultimately determined that the covenants at issue in the Agreements do not run with the land, as the Debtors and the Court believes to be the case, the Debtors will be free to negotiate new gas gathering agreements with any party, likely obtaining better terms than the existing agreements provide. If, however, the covenants are ultimately determined to run with the land, the Debtors will likely need to pursue alternative arrangements with [the pipeline operators] consistent with the covenants by which the Debtors would be bound. In either scenario, the Debtors’ conclusion that they are better off rejecting the [gathering] Agreements is a reasonable exercise of their business judgment. Therefore, even though, as explained below, the Court’s conclusion that the covenants at issue do not run with the land is non-binding, the Court finds that the Debtors’ decision to reject each of the [gathering] Agreements to be a reasonable exercise of business judgment.
Applying Texas law, the Court noted that “language in a contract containing a covenant is the primary evidence of the parties’ intent, but terminology is not dispositive.” Instead, applying admittedly archaic property law principles, the Court determined that a covenant runs with the land when, among other elements, and it “touches and concerns the land.” The Court also considered whether there was “horizontal privity of estate,” which traditionally involves a property owner reserving, by covenant, an interest in the property for a third party.
Under the Court’s analysis, the primary terms of the gathering agreements relate to the rights and obligations regarding the oil and gas rather than to the land or leasehold interests from which they came. Further, the right to transport and transform the oil and gas products is not one of the property rights of a mineral estate under Texas law. The Court went on to find that to “touch and concern the land,” a covenant must affect the owner’s interest or its use of the land, and the gathering fee covenant had no direct impact on the land or on Sabine’s property rights.
While this ruling may fuel a driller’s desire to re-negotiate more favorable terms with pipeline operators, the impact of the non-binding ruling is still limited to the specific terms of those gathering agreements and the state law governing those agreements.
There are plenty of contract drafting questions to consider in light of the ruling. The Court distinguished certain cases where covenants were found to grant property interests, and arguably drafters could work to more closely mirror those covenants and the underlying provisions to create a genuine property interest.
Another option may be to consider an entirely different drafting approach, such as structuring the gathering agreements as forward contracts and/or swaps, especially in light of the CFTC’s recent willingness to include transportation and tolling agreements in the definition of a swap. Such a designation could potentially bring these contracts under the safe harbor provisions of the Bankruptcy Code, and the parties’ initial intent to have a gathering agreement survive a driller’s bankruptcy could be preserved.