The United States does not have one electricity market. It has a collection of regional systems, each with its own generation base, transmission network, weather exposure, demand profile, and market rules. National headlines about AI, data centers, electrification, and grid investment matter. They do not, by themselves, explain where power is tight, where prices are forming, or where investors can access the market.

Power demand may be a national story. Power prices are not.

For MWHS, ERCOT—the Electric Reliability Council of Texas—and PJM Interconnection are the two focal markets. Each has transparent wholesale price formation and established listed futures benchmarks. More important, each brings together four features that do not always coexist: visible structural pressure, identifiable regional price signals, established futures markets, and access through standardized contracts. That combination makes ERCOT and PJM more than regional grid stories. They are the principal markets through which investors can evaluate—and obtain futures-based exposure to—U.S. wholesale electricity pricing.

ERCOT: Texas Sets Its Own Conditions

ERCOT serves most of Texas and is largely electrically separate from the two major U.S. interconnections. The distinction is consequential. When Texas demand rises sharply or available supply becomes constrained, ERCOT has limited ability to draw substantial volumes of electricity from neighboring systems. Conditions inside the state therefore carry unusual weight in wholesale price formation.

Texas is adding demand from several directions at once: population growth, industrial development, large commercial facilities, and data-center construction. ERCOT’s planning materials have reflected a sharply higher long-term load outlook, with a meaningful portion tied to proposed large-load facilities. Forecasts are not price predictions. They do show why the relationship among load growth, generation development, transmission capability, and reserve conditions has become a central market question.

ERCOT uses locational pricing. Electricity does not carry a uniform value across the state at every moment. Price differences emerge when transmission limits make it difficult to move lower-cost generation to a particular area, or when local supply and demand conditions diverge. A statewide demand forecast supplies context; the economic effect is ultimately local.

ERCOT is therefore more than a Texas growth story. It is a wholesale market in which weather, load, fuel availability, generation outages, and transmission constraints can be reflected directly in real-time and forward power prices.

PJM: Scale Does Not Eliminate Constraint

PJM operates across all or parts of 13 states and the District of Columbia. It is one of the largest wholesale electricity markets in the country, with day-ahead and real-time energy markets, a forward capacity market, ancillary-service markets, and transmission-related pricing mechanisms.

Its scale creates a different market picture from ERCOT’s. PJM has a broad, interconnected footprint and more avenues for moving power across regions. It also has a layered set of price signals. Day-ahead and real-time prices reflect current market conditions. Capacity auctions establish prices for resources intended to support future reliability. Transmission constraints can still create meaningful differences within the larger footprint.

Northern Virginia illustrates why PJM requires local analysis despite its scale. The region is one of the world’s largest concentrations of data centers, placing a substantial source of new load within PJM. Serving that demand is not merely a question of how much electricity the overall system can produce. It depends on where generation is located, whether transmission can deliver it, how quickly projects can interconnect, and how the market assesses future resource adequacy.

PJM’s size provides flexibility. It does not make the market uniform. The demand outlook in Northern Virginia can have different implications from conditions in western PJM or elsewhere in the footprint. A large regional grid still produces regional price signals.

Two Markets, Two Forms of Price Discovery

ERCOT and PJM are often grouped together because both sit at the center of U.S. electricity futures. The comparison is useful because their differences are material.

ERCOT’s largely isolated structure places greater emphasis on conditions within Texas. PJM’s interconnection and capacity construct create a broader, more complex set of market signals. ERCOT is often assessed through Texas weather, load growth, available supply, and transmission constraints. PJM requires attention to energy pricing, capacity outcomes, transmission development, and the geography of large-load additions.

Electricity is difficult to store economically at system scale in the way many other commodities can. Power must be produced, delivered, and consumed as the system requires it. When supply, demand, or transmission conditions fall out of balance, that pressure can register quickly in spot prices and in expectations embedded in forward markets. Listed ERCOT and PJM futures were developed in part to help commercial participants manage regional price risk. They also provide standardized benchmarks through which investors can obtain futures-based exposure to forward wholesale power prices.

This is where the Power Shift thesis becomes observable. Demand growth, transmission bottlenecks, changes in available generation, and regional load concentration are not abstract inputs. In ERCOT and PJM, they can affect the daily mechanics of wholesale power pricing and the expectations embedded in forward markets. The relevant question is not whether a national electricity theme exists; it is where those conditions are becoming material enough to register in a specific market.

The Skylar Electricity Futures ETF (NYSE Arca: MWHS) Fits

MWHS is not a broad energy-theme fund. The Skylar Electricity Futures ETF (NYSE Arca: MWHS) seeks capital appreciation primarily through investments in U.S. electricity futures contracts, with a primary focus on ERCOT and PJM—two defined wholesale markets rather than a collection of companies tied indirectly to the power system. The intended exposure is to regional electricity-price dynamics, not to a general energy narrative.

The Fund’s market focus does not represent a forecast about any particular weather event, grid condition, or power-price outcome. Electricity futures are specialized instruments and can be volatile. Their prices may be affected by regional weather, fuel costs, generation availability, reserve conditions, congestion, transmission constraints, liquidity, and changes in market or regulatory structure.

ERCOT and PJM provide the clearest entry point for understanding what makes electricity distinct: not a national abstraction, but a set of regional markets in which the economics of power are priced every day.

Important Information

The Skylar Electricity Futures ETF (NYSE Arca: MWHS) seeks capital appreciation primarily through investments in U.S. electricity futures contracts. The Fund is subject to substantial risk, including commodity futures risk, derivatives risk, market volatility, regional concentration risk, liquidity risk, and regulatory or market-structure risk. Because the Fund focuses on electricity futures in ERCOT and PJM, its performance may be significantly affected by regional weather events, fuel input costs, transmission constraints, grid conditions, and changes in supply-demand dynamics.

An investment in MWHS is not a bank deposit, is not insured by the FDIC or any other government agency, and may lose value. Past performance does not guarantee future results. Investors should consider the Fund’s investment objectives, risks, charges, and expenses carefully before investing. The prospectus and summary prospectus contain this and other information and should be read carefully before investing.