FERC Approves Largest Enforcement Settlement In Nearly Four Years RSS Feed

FERC Approves Largest Enforcement Settlement In Nearly Four Years

On February 1, 2017, the Federal Energy Regulatory Commission (FERC or the “Commission”) approved a settlement agreement between its Office of Enforcement (Enforcement) and GDF SUEZ Energy Marketing NA, Inc. (GSEMNA) resolving Enforcement’s investigation into whether GSEMNA violated the Commission’s Anti-Manipulation Rule. To resolve the matter, GSEMNA agreed to pay a civil penalty of $41 million, disgorge $40.8 million in unjust profits and undertake compliance reporting. The settlement is significant for two key reasons. First, it reflects the Commission’s continued use of its anti-manipulation authority to prosecute “gaming” of organized wholesale electric markets (i.e., RTOs and ISOs) through bidding strategies that technically comply with market rules, but are inconsistent with the “purpose” of the rules—one of the more controversial theories of market manipulation pursued by FERC in recent years. Second, the $81.8 million settlement is the largest enforcement settlement in almost four years, and it comes at a time when subjects of enforcement actions are increasingly deciding to litigate cases rather than settle with FERC—particularly when major civil penalty and disgorgement amounts are at stake.

Conduct at Issue
This case concerns the PJM Interconnection, L.L.C. (PJM) wholesale electric markets and, specifically, PJM’s market rules that allow certain generators to collect revenues associated with lost opportunity credits (LOCs). The PJM tariff provides for payment of LOCs to combustion turbines (CTs) and certain other generators that clear the day-ahead (DA) energy market, but are not dispatched in the real-time (RT) market. PJM established LOCs to encourage generators to keep their resources as part of PJM’s pool-scheduled resources and thereby allow PJM to control their output to manage system operations and maintain reliability. In essence, PJM’s grid management and dispatch decisions benefit from the flexibility afforded by having control over these generators—and the generator owners are willing to cede that control because of lost opportunity payments they could obtain when PJM decides not to run their plants.

The key issue in the investigation turned on when and how LOCs were paid out and whether GSEMNA engaged in a scheme to improperly take advantage of PJM’s LOC payment formulas to obtain LOC dollars it should not have obtained. As to the payment formula details, during the May 2011 to September 2013 time period at issue, PJM paid LOCs equal to the higher of (a) the difference between the RT locational marginal price and the DA locational marginal price, or (b) the difference between the RT locational marginal price and the higher of the unit’s price-based or cost-based incremental energy offers. The LOC formula did not subtract start-up and no-load costs, although such costs would be incurred if the unit were dispatched by PJM in the RT market. As a result, a generator with a DA award could earn a greater margin when it received LOCs and was not dispatched in the RT market than it would have earned if it was dispatched.

Beginning in or around June 2011, GSEMNA implemented a strategy to profit from LOCs by offering CT units in the DA market below the CT units’ calculated costs with the goal of clearing the DA market and then collecting LOCs if the units were not dispatched. GSEMNA discounted its DA price-based offers below calculated costs, knowing that the CT units likely would run at a loss if dispatched. In November 2011, after PJM corrected an error in which it was calculating LOCs based on price-based offers rather than the higher of the price-based or cost-based offers as required by its tariff, GSEMNA began discounting the cost-based offers for the units to the level of its price-based offers. As a result, the LOCs that GSEMNA received for the CT units would continue to be based on the discounted offer and would be higher than if they were based on estimated costs. GSEMNA continued to implement its strategy during the relevant period by discounting a given CT unit’s DA offer based on an assessment of the likelihood that the CT unit would not be dispatched in the RT market, weighing the risk of running the CT unit at a loss if dispatched against the potential reward of LOCs if not dispatched. At times, GSEMNA discounted offers for the CT units to get DA awards in order to obtain LOCs by offering the units with discounts as deep as -$25/MWh. When GSEMNA expected a CT unit to be dispatched in the RT market, it did not discount its DA offer, and GSEMNA typically did not discount offers for units that were not eligible for LOCs.

Enforcement’s Findings
Enforcement concluded that GSEMNA violated the Anti-Manipulation Rule by engaging in a strategy to target and inflate the receipt of LOCs in PJM. Enforcement found that GSEMNA’s strategy of targeting and inflating LOCs was “contrary to supply and demand fundamentals” and “impaired the functioning of the LOC provisions of the PJM market and PJM’s unit commitment process.”1 Enforcement found that GSEMNA’s offers “did not reflect the price at which it wanted to generate power, but rather the price at which it could obtain a DA award and then receive LOCs during periods when the discounted CT units likely could not be operated economically”—conduct Enforcement concluded was “contrary to LOCs’ purpose of compensating generators for lost opportunity costs due to PJM’s decision not to dispatch a generation unit.”2

Key Takeaways
Only the fourth “gaming” settlement. While FERC’s pursuit of electric market “gaming”3 cases has gained much attention in the industry, Enforcement has brought relatively few of these cases to date (whether through settlements or Orders to Show Cause and follow-on federal court litigation). This case is only the fourth such settlement. The other three were a $410 million settlement with JP Morgan Ventures Energy Corporation (JPMVEC) in 2013 for various bidding strategies in California (CAISO) and Midcontinent (MISO) markets, an approximately $81,000 settlement with Oceanside Power, LLC in 2013 for an up-to congestion product bidding strategy in PJM and an $8 million settlement with Maxim Power Corp. for certain bidding activities in ISO New England.4
Largest settlement in almost four years. In recent years, subjects in enforcement cases have increasingly elected to defend themselves in court rather than settle, particularly in cases involving large civil penalties. This case is by far the largest enforcement settlement in almost four years since JPMVEC’s $410 million settlement in 2013. On the other hand, there are several cases involving potential eight-or nine-figure penalties that are being contested at the Commission or in court…..

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