Cheaper Electricity In Texas

Timing is everything in the Texas electricity market. The difference between renewing your commercial electricity contract at the right time versus the wrong time can amount to tens of thousands of dollars over the life of your agreement. Yet most Texas businesses treat contract renewal as an afterthought — something they deal with reactively rather than strategically. In a deregulated market like ERCOT , you have the power to choose your supplier and negotiate your terms. But that power is only useful if you exercise it at the right moment. This guide explains exactly when and how to approach your commercial electricity contract renewal for maximum savings. Know Your Contract End Date This sounds obvious, but it is the number one reason businesses overpay for electricity. The majority of commercial customers we work with do not know when their current electricity contract expires until it is too late. When your contract ends without a new agreement in place, one of two things typically happens — and neither one is good for your business: Auto-renewal at a holdover rate. Some contracts include a provision that automatically rolls you into a new term, but at a significantly higher rate. These holdover rates are rarely competitive — they are set by the REP without any negotiation, and they can be 20-50% above market rates. Month-to-month variable pricing. Without a contract in place, you default to a month-to-month variable rate that fluctuates with the wholesale market. This means you have no price protection during peak demand periods when electricity is most expensive. Both scenarios cost you money, and both are entirely avoidable. The fix starts with one simple action: find out when your current contract ends and put that date on your calendar — with a reminder set 120 days in advance. The 3-4 Month Rule The single most important tactical advice for contract renewal is this: start shopping 90 to 120 days before your contract expires. There are several reasons this timeline works: Forward pricing availability. Electricity suppliers offer forward pricing — rates locked in today for a future start date. These forward offers are typically available 30 to 120 days out. Starting early gives you access to the widest range of forward pricing options. Competitive leverage. When suppliers know you are shopping well in advance, they compete harder for your business. A business that calls one week before contract expiration has limited leverage because the supplier knows you are under time pressure. Time to compare. Evaluating bids from multiple suppliers takes time. You need to compare not just the headline rate, but the contract terms, fee structures, pass-through mechanisms, and early termination provisions. Our guide to fixed vs. variable rate electricity breaks down each option. Rushing this process leads to overlooked details that cost money. Market flexibility. Starting early means you can watch the market for favorable pricing windows. If rates are trending down, you can wait a few weeks. If rates are about to spike (heading into summer, for example), you can lock in before the increase. The Renewal Timeline 120 days out: Begin gathering your usage data and contacting brokers or suppliers. 90 days out: Review competitive bids and compare options. 60 days out: Finalize your selection and execute the contract. 30 days out: Confirm the switch is on track with your new supplier and ERCOT. Market Timing: When Are Texas Electricity Prices Lowest? The Texas electricity market follows predictable seasonal patterns driven largely by weather and natural gas prices. Understanding these patterns can help you time your contract renewal for the best possible rates. Generally, the best time to lock in a commercial electricity rate in Texas is between October and March. During this window, electricity demand is lower (mild weather means less HVAC load), natural gas prices — which drive the marginal cost of electricity generation in Texas — tend to be more stable, and suppliers are more willing to offer competitive forward pricing to secure volume for the coming year. Conversely, the most expensive time to sign a contract is during the summer months, particularly June through August. Wholesale prices are elevated due to peak cooling demand, and suppliers price their forward contracts to reflect the risk of extreme heat events. If you lock in a 24- or 36-month contract at summer peak pricing, you are paying an inflated rate for the entire term — not just the summer months. Timing your contract renewal to coincide with lower market periods can save your business thousands over the contract term. That said, the "best time" is a general guideline, not a guarantee. Unusual weather patterns, natural gas supply disruptions, changes in generation capacity, and regulatory developments can all move prices outside of their typical seasonal ranges. This is why ongoing market monitoring matters — and why working with a professional who tracks these factors daily is so valuable. Watch the Calendar, Not Just the Market Beyond general seasonal trends, several specific calendar events and market factors can significantly impact electricity pricing in Texas: ERCOT capacity and reserve margin reports. ERCOT publishes seasonal assessments of expected generation capacity versus demand. When reserve margins are tight — meaning the grid has less cushion between available supply and expected demand — forward prices tend to rise as suppliers price in the higher risk of scarcity events. Hurricane season (June-November). Gulf Coast hurricanes can disrupt natural gas production and electricity transmission infrastructure. The mere forecast of an active hurricane season can push forward prices higher as suppliers hedge against potential supply disruptions. Planned generation outages. Power plants schedule maintenance during lower-demand periods, but the timing and duration of these outages affects available supply. When multiple plants are offline simultaneously, prices can rise even during typically mild periods. Natural gas market movements. Since natural gas is the primary fuel for Texas electricity generation, significant movements in the Henry Hub benchmark directly impact electricity forward pricing. A cold winter that drives up natural gas demand nationally can raise Texas electricity prices even before summer arrives. Tracking all of these factors yourself is a full-time job. This is one of the core services an energy broker provides — continuous market monitoring so that when it is time to renew your contract, you are making a decision based on current conditions, not last month's assumptions. Early Termination: When It Makes Sense to Break a Contract Sometimes the smartest move is not waiting for your contract to expire — it is getting out early. If market rates have dropped significantly below your current locked-in rate, paying the early termination fee (ETF) and signing a new contract at lower rates can actually save you money over the remaining term. Here is how to evaluate whether early termination makes financial sense: Calculate your remaining cost. Multiply your current rate by your expected consumption for the remaining months of your contract. This is what you will pay if you stay. Get current market pricing. Obtain competitive bids for a new contract covering the same remaining period. Calculate what you would pay at the new rate. Add the ETF. Your current contract specifies the early termination fee — typically a per-kWh charge multiplied by your remaining expected usage, or a flat dollar amount. Compare totals. If the new contract cost plus the ETF is less than the cost of staying on your current contract, early termination is the financially rational choice. This calculation is straightforward in principle, but the details matter. Some ETFs are structured to decrease over the contract term, making termination more attractive as you approach expiration. Others have minimum charges that make early termination prohibitively expensive regardless of market conditions. An experienced broker can run these numbers for you and tell you exactly where the break-even point is. How a Broker Helps With Contract Renewals The businesses that consistently get the best electricity rates in Texas are not the ones who happen to get lucky with timing. They are the ones who have a professional managing their energy procurement on an ongoing basis. Here is what a good energy broker does for you around contract renewal: Tracks your contract dates. You do not need to set calendar reminders or dig through filing cabinets to find your contract terms. Your broker knows exactly when every agreement expires and starts the renewal process at the optimal time. Monitors market conditions. Instead of checking electricity prices yourself (which most business owners have neither the time nor the expertise to do meaningfully), your broker is watching daily market movements and will advise you on when conditions favor locking in a rate. Solicits competitive bids. Rather than calling individual REPs one at a time, your broker sends your usage profile to 25+ suppliers simultaneously, generating a competitive bidding environment that drives prices down. Reviews contract terms. The headline rate is only part of the picture. Your broker reviews the full contract for unfavorable terms, hidden fees, pass-through mechanisms, and termination provisions that could cost you down the line. Provides continuity. Your broker retains your historical usage data, knows your business's energy profile, and understands your preferences from previous renewal cycles. This institutional knowledge means each renewal is more efficient and better tailored than the last. All of this comes at no cost to your business — the broker is compensated by the supplier, not by you.  A broker manages the entire renewal process — from market monitoring to contract execution — so you can focus on running your business. Take Control of Your Next Renewal Your commercial electricity contract is one of the largest controllable expenses in your business. Treating renewal as a strategic decision rather than an administrative task can save you thousands of dollars every year. The key principles are simple: know your contract end date, start shopping 90-120 days early, time your renewal to avoid peak market periods, and work with a professional who monitors the market and negotiates on your behalf. For more ways to reduce costs, see our guide to lowering commercial electricity bills . Businesses that follow this approach consistently pay less for electricity than those who let contracts auto-renew or wait until the last minute. If you do not know when your current contract expires, that is the first thing to fix.

Texas is one of the few states in the country with a fully deregulated electricity market. That means businesses operating within the ERCOT grid have the freedom to choose their Retail Electric Provider (REP) — a significant advantage that can translate into real savings on one of your largest operating expenses. But freedom of choice comes with complexity. There are more than 25 licensed REPs serving the Texas commercial market, each offering dozens of plans with varying rate structures, contract terms, and fee schedules. Navigating this landscape on your own is time-consuming, and without market expertise, it is easy to leave money on the table. That is why a growing number of Texas businesses — from single-location restaurants to multi-site industrial operations — work with energy brokers rather than going directly to providers. What Does an Energy Broker Actually Do? An energy broker acts as an intermediary between your business and multiple electricity suppliers. Rather than you contacting each REP individually to request pricing, your broker handles the entire process on your behalf. Here is how it typically works: The broker collects your usage data. This includes your historical consumption (usually 12 months of usage history), your current rate and contract terms, your meter information, and your TDU service area. The broker solicits competitive bids. Using your usage profile, the broker requests pricing from multiple suppliers simultaneously. This creates a competitive bidding environment — suppliers know they are competing against each other, which drives prices down. The broker presents your options. You receive a side-by-side comparison of bids from multiple suppliers, including the rate per kWh , contract length, rate structure ( fixed, variable, or hybrid ), and any fees or special terms. You choose. The broker explains the options and makes recommendations based on your business's needs, but the final decision is always yours. The broker manages the transition. Once you select a supplier, the broker handles the contract execution and coordinates with ERCOT for the switch. There is no interruption to your service.  The most important thing to understand is that the broker is paid by the supplier, not by you. REPs build a small commission into their pricing to compensate the broker. This is the same commission structure that exists whether you go through a broker or not — when you go direct, the REP's internal sales team earns that same margin. Using a broker does not add cost to your bill.

When most Texas business owners think about their electricity cost, they think about one number: the per-kWh rate. That number represents energy charges — what you pay for the volume of electricity you consume. But hidden beneath that headline rate is a second, often larger cost component that most businesses never scrutinize: capacity charges. These charges — which show up as demand charges , transmission demand fees, and various per-kW assessments — pay for the grid's ability to deliver power at your peak consumption level, regardless of how much total energy you use. Understanding the fundamental difference between energy and capacity costs is essential for commercial electricity buyers who want to move beyond surface-level rate shopping and actually control their total cost of power. This guide breaks down both cost components in depth, explains how each is calculated, identifies the trends driving each component, and provides strategies for managing both. The Fundamental Distinction Every dollar on your commercial electricity bill ultimately pays for one of two things: Energy Costs: Paying for Fuel and Generation Energy charges pay for the actual electricity you consume — the kilowatt-hours (kWh) that powered your lights, HVAC, equipment, and operations during the billing period. These charges reflect the cost of generating electricity: the fuel (natural gas, wind, solar), the operating costs of power plants, and the wholesale market dynamics that determine the price at which generators sell their output. Energy charges are volumetric — they scale directly with how much electricity you use. If you use twice as much electricity, your energy charges roughly double. If you shut down for a week, your energy charges drop proportionally. On your bill, energy charges typically appear as: Energy charge (per kWh) from your REP TDU energy delivery charge (per kWh) from your TDU Fuel factor or energy pass-through charges (on some contract structures)  Capacity Costs: Paying for Infrastructure and Readiness Capacity charges pay for the grid's ability to deliver power at the rate you need it — measured in kilowatts (kW) of peak demand. These charges cover the physical infrastructure (transformers, substations, distribution lines, transmission towers) that must be sized to handle your maximum draw, the generation capacity that must be available to serve peak system-wide demand, and the ancillary services that keep the grid stable. Capacity charges are demand-based — they scale with the highest rate at which you consume electricity at any point during the billing period, not the total volume you consume. Two businesses can use the exact same total kWh in a month but pay dramatically different capacity charges if one draws power steadily and the other draws it in sharp peaks. On your bill, capacity charges typically appear as: TDU demand charge (per kW) — often the largest single capacity-related line item Transmission demand charge (per kW) — covering high-voltage transmission infrastructure REP demand charge (per kW) — some contracts include a supply-side demand component Coincident peak (4CP) charges — based on your usage during ERCOT system peak periods Capacity obligation or ancillary service charges — covering grid reliability requirements

Restaurants are among the most energy-intensive businesses in the commercial sector. Between commercial kitchen equipment running at full capacity during service, walk-in coolers and freezers operating around the clock, HVAC systems battling Texas heat, and hood ventilation fans that never stop, electricity is often the second-largest operating expense for Texas restaurants — right behind labor. Our restaurants and food industry page covers how we help operators across the state. The good news is that operating in ERCOT's deregulated electricity market means you have options. Unlike states where a single utility dictates your rate, Texas restaurant operators can choose their commercial electricity supplier, negotiate their contract terms, and implement operational strategies that directly reduce what they pay. This guide covers the practical, high-impact actions you can take to bring those electricity costs down. Why Restaurant Electricity Bills Are So High Before you can fix the problem, it helps to understand why restaurants use so much electricity compared to other commercial businesses of similar size. The answer comes down to two factors: total consumption and peak demand. On the consumption side, restaurants operate energy-hungry equipment for extended hours: Walk-in coolers and freezers run 24 hours a day, 7 days a week. These are the baseline of your electricity usage, drawing power even when the restaurant is closed. Commercial ovens, fryers, and grills consume massive amounts of electricity during prep and service. A single commercial convection oven can draw 10-15 kW. HVAC systems work overtime in Texas, especially from May through September. The kitchen generates significant heat, so your cooling system is not just fighting outdoor temperatures — it is fighting the heat your own equipment produces. Hood ventilation systems are required by code to run whenever cooking equipment is in operation, and they pull conditioned air out of the building, forcing the HVAC to work harder. Lighting, POS systems, dishwashers, and ice machines round out a substantial base load that runs through every shift. All of this equipment running simultaneously is what drives the second factor — peak demand — which is where the real cost pain point lies for most restaurants.

If you own or manage a business in Texas, you have a choice that most Americans do not: you get to pick who supplies your electricity. Texas operates one of the largest deregulated electricity markets in the world, which means the power you use is not tied to a single monopoly utility. Instead, dozens of competing suppliers bid for your business, and you choose the plan that fits your budget, risk tolerance, and usage pattern. That freedom is powerful — but only if you understand how the system actually works. This guide breaks down the Texas deregulated electricity market from the ground up, so you can make informed decisions whether you are signing your first commercial contract or re-evaluating your current one. What Does "Deregulated" Actually Mean? Before 2002, electricity in Texas worked like it does in most states: a single utility company generated the power, delivered it through its own wires, and billed you for it. You had no choice of provider and no leverage on price. The utility set the rates, the Public Utility Commission of Texas (PUCT) approved them, and that was that. In 1999, the Texas legislature passed Senate Bill 7, which restructured the electricity market. By January 2002, the retail electricity market opened to competition in most of the state. The core idea was simple: separate the competitive parts of the business (generating and selling electricity) from the natural monopoly parts (the physical wires and poles that deliver it). The result is a market where multiple companies compete to sell you electricity at different prices and contract terms, while the delivery infrastructure remains regulated and operated by a single entity in each service area. The Three Players in the Texas Electricity Market Understanding deregulation starts with knowing who does what. There are three distinct roles in the Texas electricity supply chain: 1. Power Generators These are the companies that own and operate the power plants — natural gas facilities, wind farms, solar arrays, and nuclear plants. They produce the electricity that flows into the grid. In Texas, no single generator dominates the market. Dozens of companies compete to produce power at the lowest cost, and their output is sold on the wholesale market managed by ERCOT (the Electric Reliability Council of Texas). 2. Transmission and Distribution Utilities (TDUs) TDUs own and maintain the physical infrastructure — the power lines, transformers, substations, and meters that deliver electricity from the generators to your building. In the Houston area, for example, CenterPoint Energy is the TDU. In Dallas-Fort Worth, it is Oncor. These companies do not sell you electricity. They are regulated monopolies responsible solely for delivery and maintaining the grid. TDU charges appear on your electricity bill as delivery fees, and they are the same regardless of which retail electricity provider you choose. You cannot shop for a different TDU — that is determined by your physical location. 3. Retail Electricity Providers (REPs) REPs are the companies you actually choose and sign a contract with. They buy electricity on the wholesale market (or generate their own) and sell it to you at a retail rate. REPs compete on price, contract terms, customer service, and plan features. There are over 100 active REPs in Texas, ranging from national brands to small regional suppliers. Your REP is the company that sends you a bill, and the one you negotiate your rate with. When people talk about "switching electricity providers," they mean switching REPs. The TDU and the physical delivery of your power stay exactly the same — the electrons flowing through the wires do not change. What changes is who you pay, how much you pay, and under what contract terms.

If you have ever looked at your commercial electricity bill and wondered why it is so much higher than the per-kWh rate would suggest, there is a good chance the answer is demand charges. For many Texas businesses, demand charges account for 30% to 70% of the total electricity bill — yet most business owners have never heard of them until they see the number. This guide explains what demand charges are, how they are calculated, why they exist, and what you can do to manage them. Energy Charges vs. Demand Charges Your commercial electricity bill has two main components, and understanding the difference between them is essential: Energy charges measure how much total electricity you consumed during the billing period. This is the per- kilowatt-hour (kWh) rate that most people focus on. If you used 50,000 kWh in a month at $0.08/kWh, your energy charge is $4,000. This is the volume of electricity you consumed. Demand charges measure the highest rate at which you consumed electricity at any single point during the billing period. This is measured in kilowatts (kW), not kilowatt-hours. It reflects the peak load your building placed on the grid — the maximum amount of power you drew at one time. If your peak demand was 200 kW and your demand rate is $10/kW, your demand charge is $2,000. Think of it this way: energy charges are like paying for the total gallons of water you used in a month. Demand charges are like paying for the size of the pipe needed to deliver water at your peak usage moment. Even if you only turned on every faucet simultaneously for fifteen minutes, you still needed that large pipe — and you pay for it. How Demand Charges Are Calculated Your TDU (Transmission and Distribution Utility) measures your electricity usage in 15-minute intervals throughout the billing period. At the end of the month, they identify the single 15-minute interval where your average power draw was highest. That peak — measured in kilowatts — becomes your billed demand for the month. Here is a concrete example. Suppose your business operates a restaurant. For most of the day, your kitchen equipment, HVAC, and lighting draw about 80 kW. But during the Friday dinner rush, the kitchen runs every piece of equipment simultaneously, the dining room lights are at full brightness, and the HVAC is fighting the heat from the kitchen — your load spikes to 180 kW for about 45 minutes. Your billed demand for the entire month is 180 kW, even though you only hit that level for a brief period. If your demand rate is $12/kW, that spike alone adds $2,160 to your bill — roughly the same as running at 80 kW for the entire month would cost in demand charges ($960).  This is why demand charges feel disproportionate. A single peak event — even one lasting just 15 minutes — sets your demand charge for the entire billing cycle.

A commercial electricity bill in Texas is not designed to be intuitive. Between TDU delivery charges, REP energy charges, demand fees, pass-throughs, and regulatory line items, even experienced business owners struggle to understand where their money is going. And if you cannot read your bill, you cannot evaluate whether you are overpaying. This guide walks through every section of a typical Texas commercial electricity bill, explains what each charge means, and shows you which numbers actually matter when you are comparing rates or negotiating a new contract. The Two Bills on Your Bill The first thing to understand is that your commercial electricity bill in a deregulated area is actually two sets of charges combined into one statement: Energy supply charges — from your REP (Retail Electricity Provider). This is the company you chose and signed a contract with. These charges cover the actual electricity you consumed. Delivery charges — from your TDU (Transmission and Distribution Utility). This is the company that owns the wires and poles — CenterPoint in Houston, Oncor in Dallas, etc. These charges cover getting the electricity to your building. Most commercial bills consolidate both into a single statement from your REP, but the charges come from two different companies. This distinction matters because you can shop and negotiate your REP charges, but TDU charges are regulated and the same regardless of which REP you use. Section 1: Account and Meter Information The top of your bill typically shows: Account number — Your unique identifier with the REP. ESI ID (Electric Service Identifier) — A 17- or 22-digit number that identifies your specific meter and service point on the ERCOT grid. This is the number that matters when switching REPs or getting quotes. Every meter has a unique ESI ID. Meter number — The physical meter identifier at your location. Billing period — The date range the bill covers (typically 28-32 days). Service address — The physical location being served. Why this matters: When you request quotes from other REPs or from a broker , they need your ESI ID and recent usage history. Having this information ready speeds up the process significantly. Section 2: Energy Supply Charges (REP Charges) This is the portion you can negotiate. Common line items include: Energy Charge The core charge — your per- kWh rate multiplied by total consumption. If your rate is $0.075/kWh and you used 45,000 kWh, this line item is $3,375. On a fixed-rate plan , this rate stays constant. On an index plan , it varies with the wholesale market. Base Charge or Customer Charge A flat monthly fee ($5-$25 for most commercial accounts) that covers administrative costs. This is charged regardless of how much electricity you use. REP Demand Charge (if applicable) Some REPs include a demand component on the supply side. This is separate from the TDU demand charge. It is typically a per-kW rate applied to your peak demand. Not all plans have this — it depends on your contract structure and rate class. Renewable Energy Credit or Green-e Charge If you are on a renewable energy plan, this line item covers the cost of the renewable energy certificates associated with your usage. It is usually a small per-kWh adder ($0.001-$0.005/kWh).

One of the most common points of confusion for Texas business owners is this: who is actually providing your electricity? You see CenterPoint or Oncor on your bill, but you signed a contract with a company called something else entirely. Are they the same company? Who do you call when the power goes out? Who do you negotiate rates with? The answer lies in how Texas deregulated its electricity market . In a deregulated market, the company that sells you electricity is not the same company that delivers it. Understanding this distinction is fundamental to managing your energy costs effectively. The Three Companies Behind Your Electricity In a deregulated Texas city, three separate entities are involved every time you flip a light switch: Your REP (Retail Electricity Provider) Your REP is the company you have a contract with. They are your electricity supplier — the company that buys power on the wholesale market and sells it to you at a retail rate. Your REP determines your energy rate, your contract terms, and your billing. When you "shop for electricity" or "switch providers," you are switching REPs. There are over 100 active REPs in the Texas market. Some you may have heard of — TXU Energy, Reliant, Direct Energy, Constellation. Many others are smaller regional or commercial-focused providers. The variety is the whole point of deregulation: competition drives better rates and service.  Your TDU (Transmission and Distribution Utility) Your TDU is the company that owns the physical infrastructure — the power lines, transformers, poles, and meters — that delivers electricity to your building. Unlike REPs, TDUs are regulated monopolies. You cannot choose your TDU; it is determined by your geographic location. The major TDUs in Texas are:

Electricity is one of the largest controllable operating expenses for most Texas commercial businesses — and one of the most volatile. In the ERCOT market, wholesale prices can swing from $20/MWh to $5,000/MWh within hours. Even businesses on retail contracts are exposed to this volatility at renewal time, when market conditions determine the rates available to them. For CFOs, facility managers, and procurement teams, the question is not whether to manage electricity price risk — it is how. This guide covers the full spectrum of hedging strategies available to Texas commercial electricity buyers, from the simplest (fixed-rate contracts) to the most sophisticated (layered procurement with financial instruments). Each strategy has trade-offs between cost certainty, potential savings, complexity, and risk. Understanding these trade-offs is essential for making procurement decisions that align with your business's financial objectives and risk tolerance.. Why Electricity Price Volatility Matters to Your Business Before diving into hedging strategies, it is worth quantifying why electricity price risk deserves active management — particularly in Texas. ERCOT Is Uniquely Volatile The Texas electricity market is more volatile than most U.S. power markets for several structural reasons: Energy-only market design. Unlike PJM, MISO, or ISO-NE, ERCOT does not have a capacity market that pays generators to be available. Revenue comes entirely from energy and ancillary service sales, which means prices must spike high enough during scarcity events to keep generators economically viable year-round. This design intentionally produces higher price spikes than capacity-market regions. Extreme weather exposure. Texas faces both extreme summer heat (driving cooling demand to record levels) and periodic severe winter events. The February 2021 Winter Storm Uri saw prices sustained at the then-$9,000/MWh cap for multiple days. Summer heat waves regularly push real-time prices above $1,000/MWh for extended afternoon periods. High renewable penetration. Texas leads the nation in wind generation and has rapidly growing solar capacity. While this provides abundant low-cost energy during favorable conditions (driving prices to zero or negative), it also creates "wind drought" and "solar duck curve" dynamics that amplify price spikes when renewable output drops during high-demand periods. Grid isolation. The ERCOT grid is largely disconnected from the rest of the U.S. power grid. When supply is tight, Texas cannot easily import electricity from neighboring regions, which concentrates price pressure within the state. The Business Impact Is Real For a Texas business consuming 100,000 kWh per month, the difference between a $0.07/kWh rate and a $0.12/kWh rate is $5,000 per month — $60,000 per year. For a multi-location operation consuming 500,000+ kWh per month, rate differences translate to hundreds of thousands of dollars annually. These are not hypothetical swings — they represent the actual range of rates available to commercial customers depending on when they contract and what structure they choose. More critically, businesses on expired contracts or poorly timed renewals can face even larger cost increases. The goal of hedging is not to eliminate all price risk (that is neither possible nor desirable) but to manage it so that electricity costs are predictable enough to protect margins and support financial planning. The Hedging Spectrum: From Simple to Sophisticated Commercial electricity hedging exists on a spectrum. At one end is a simple fixed-rate retail contract — the most basic hedge. At the other end are multi-layered procurement strategies using financial instruments, blended structures, and active portfolio management. Most Texas businesses should be somewhere on this spectrum; very few should be at either extreme.  Strategy 1: Full Fixed-Rate Contract The simplest hedge available. You sign a fixed-rate contract with a REP for 12-36 months. Your per-kWh energy rate is locked for the entire term, regardless of what happens in the wholesale market.

Your commercial electricity contract has an end date. If you do not sign a new contract before that date, your power does not get shut off — but what does happen can cost your business thousands of dollars per month. In the Texas deregulated market , an expired contract means you are automatically moved to a month-to-month holdover rate that is almost always dramatically more expensive than any contracted rate you could get. This guide explains exactly what happens when your commercial electricity contract expires, how much it can cost you, and how to make sure it never happens to your business. The Holdover Rate: What It Is and Why It Exists When your electricity contract reaches its end date and you have not signed a new agreement, your REP does not disconnect your service. Instead, they move you to what is commonly called a holdover rate, month-to-month rate, or default variable rate. Different REPs use different terminology, but the result is the same: you continue receiving electricity, but at a significantly higher price. Holdover rates exist because the REP is now supplying your electricity without the certainty of a long-term contract. They are buying power on the wholesale market to serve you but have no commitment from you on volume or duration. That uncertainty carries a risk premium — and the REP passes that risk premium directly to you in the form of a higher rate. How much higher? Holdover rates are typically 50% to 200% above what you would pay on a negotiated contract. For a business consuming 50,000 kWh per month, the difference between a contracted rate of $0.07/kWh and a holdover rate of $0.14/kWh is $3,500 per month — $42,000 per year in unnecessary cost. Why So Many Businesses End Up on Holdover Rates Despite the massive cost difference, a surprising number of Texas businesses are on holdover rates right now without realizing it. The most common reasons: The contract expired and nobody noticed. For many businesses, the electricity contract was signed two or three years ago by someone who may no longer be with the company. The end date came and went, and no one in the organization tracked it. The renewal notice was missed or ignored. Most REPs send a renewal notice 30-60 days before contract expiration. These notices often look like routine correspondence and get lost in a pile of mail or buried in an inbox. By the time someone notices, the contract has already expired. The business assumed auto-renewal at the same rate. Some business owners assume their contract will automatically renew at the same terms. In reality, most commercial contracts either expire to a holdover rate or auto-renew at a new (often higher) rate that the REP has selected — not the rate you originally negotiated. Procrastination. Shopping for a new electricity contract is not exciting work. It gets pushed to next week, next month — and suddenly you are three months past expiration, paying holdover rates the entire time.

Every commercial electricity rate in Texas — whether fixed, variable, or hybrid — is ultimately derived from the wholesale market operated by ERCOT . Understanding how wholesale pricing works gives you a significant advantage when negotiating commercial electricity contracts, evaluating rate structures, and timing your procurement decisions. This is the knowledge that separates businesses that passively accept whatever rate they are offered from those that actively manage energy as a strategic cost center. How the ERCOT Wholesale Market Works ERCOT operates two primary markets for electricity: the Day-Ahead Market (DAM) and the Real-Time Market (RTM). Both are auction-style markets where generators submit offers to sell electricity and the market clears at prices determined by supply and demand. Together, these two markets form the pricing backbone of the entire Texas electricity system. The Day-Ahead Market (DAM) The DAM operates exactly as the name implies — one day before electricity is actually consumed. Each day by 10:00 AM, generators, REPs , and other market participants submit their bids and offers for every hour of the following day. ERCOT runs a security-constrained economic dispatch algorithm that determines which generators will run and at what price for each hour. The DAM serves as the primary forward market for electricity. It allows market participants to lock in prices and quantities before real-time delivery, reducing uncertainty for both generators and load-serving entities (your REP). Roughly 95% of all electricity consumed in ERCOT is financially settled through the Day-Ahead Market. This makes it the dominant price discovery mechanism — when energy professionals talk about "the ERCOT price," they are usually referencing DAM clearing prices. DAM prices are published as Locational Marginal Prices (LMPs) for each settlement point on the grid. These LMPs reflect the marginal cost of serving the next megawatt of load at each location, accounting for three distinct components: Energy Component — The cost of generating the next MWh at the system level. This is driven primarily by fuel costs (natural gas, in most hours). Congestion Component — The incremental cost caused by transmission constraints. If a transmission line between a cheap generator and a load zone is at capacity, the congestion component reflects the cost of dispatching a more expensive local generator instead. Loss Component — The cost of electrical energy lost during transmission. Electricity dissipates as heat as it travels through wires — roughly 2-5% over long distances. Locations far from generation sources have higher loss components. These three components are additive: LMP = Energy + Congestion + Losses. Understanding this decomposition matters because it explains why two businesses in different parts of Texas can face meaningfully different wholesale costs even during the same hour. The Real-Time Market (RTM) The RTM operates continuously, dispatching generators every five minutes to balance actual supply and demand in real time. When actual conditions deviate from what was scheduled in the Day-Ahead Market — higher-than-expected demand, a generator tripping offline, unexpected wind generation — the Real-Time Market adjusts. Real-time prices are far more volatile than day-ahead prices. On a mild spring day, RTM prices might hover around $20-$30/MWh. During a summer heat wave when the grid is stressed, they can spike to $2,000-$5,000/MWh within minutes. During extreme events, ERCOT prices can hit the current system-wide offer cap of $5,000/MWh. The difference between DAM and RTM prices in any given interval is called the "basis" or "imbalance." If you bought 100 MWh in the DAM at $40/MWh but only consumed 90 MWh, the 10 MWh difference is settled at the RTM price. If the RTM price was $30/MWh, you effectively sold back 10 MWh at a $10 loss per MWh. If RTM spiked to $200/MWh, you sold back at a $160 gain. This imbalance settlement is a key source of profit and risk for REPs. For businesses on index-rate plans , the settlement mechanism in their contract determines which market — DAM or RTM — their rate is based on. This distinction matters enormously. A contract settled against real-time prices exposes you to those five-minute price spikes, while a DAM-settled contract provides somewhat more predictability. Some index products blend the two, using DAM for baseload hours and RTM for deviations.

Most Texas businesses evaluate their electricity costs by looking at two numbers: their per-kWh energy rate and their total monthly bill. But there is a third metric that has more influence on your effective electricity cost than either of those — and almost no one talks about it. That metric is your load factor. Load factor determines what percentage of your bill goes to demand charges , how competitive your rate quotes will be, and which rate structure delivers the best value for your business. Improving your load factor is often the single highest-ROI energy management action a commercial electricity customer can take. What Load Factor Is Load factor is the ratio of your average electricity demand to your peak electricity demand over a given period. It measures how consistently you use power. The formula is straightforward: Load Factor = Total kWh Consumed / (Peak Demand in kW × Hours in Billing Period) A load factor of 1.0 (or 100%) means you used electricity at a perfectly constant rate — your peak demand was the same as your average demand. A load factor of 0.3 (30%) means your average demand was only 30% of your peak — you had significant spikes relative to your baseline usage. A Concrete Example Take two businesses that both consumed 72,000 kWh in a 30-day month (720 hours):

Power Purchase Agreements have evolved from a niche procurement tool used exclusively by Fortune 500 companies into a viable option for a much broader range of Texas commercial electricity buyers. As renewable energy costs have declined precipitously — solar PPA prices have fallen over 80% since 2010 — and as corporate sustainability commitments have intensified, PPAs are now being evaluated by multi-location restaurant groups, hospital networks, large manufacturing operations , and data center operators across the ERCOT market. But a PPA is not a standard retail commercial electricity contract. It is a long-term financial instrument with real complexity, significant risks, and consequences that persist for a decade or longer. Entering a PPA without fully understanding its mechanics is one of the most expensive mistakes a commercial energy buyer can make. This guide provides a thorough examination of how PPAs work in the Texas ERCOT market, the structural differences between physical and virtual PPAs, the financial risks you must evaluate, the accounting implications, and a practical framework for deciding whether a PPA makes sense for your business.. What Is a Power Purchase Agreement? A Power Purchase Agreement is a long-term contract between an electricity buyer (the "offtaker" — your business) and a power generator (typically a wind farm or solar project developer). Under the agreement, the buyer commits to purchasing the electricity output of a specific generation project at a predetermined price for a fixed term, typically ranging from 10 to 25 years. The generator uses this committed revenue stream — the certainty of a creditworthy buyer purchasing its output for decades — to secure financing for the construction and operation of the project. This financing mechanism is the core economic rationale behind PPAs. Building a utility-scale wind farm costs $1-2 billion. Building a large solar installation costs hundreds of millions. Lenders and investors will not finance these projects without long-term revenue certainty. The PPA provides that certainty, and in return, the offtaker typically receives electricity at a price below what they would pay on the open market — particularly in later years of the agreement as retail electricity prices rise with inflation, fuel costs, and grid infrastructure investments. How PPAs Differ From Standard Retail Contracts Understanding these differences is essential before evaluating any PPA opportunity: 

Index and variable rate electricity plans are the most sophisticated — and most misunderstood — contract structures available to Texas commercial customers. Where a fixed rate plan locks in your energy charge for the duration of your contract, an index rate plan lets it fluctuate with the wholesale electricity market. The upside is real: businesses on index plans can capture lower average costs during calm market periods, sometimes saving 10-20% compared to what they would have paid on a fixed rate. The downside is also real: during extreme market events, index exposure can produce bills 5-10 times a business's normal monthly cost. Understanding index rate plans means understanding the ERCOT wholesale market — how prices are set, what drives them, and how wholesale pricing translates into your monthly bill. It also means understanding the significant regulatory changes that followed Winter Storm Uri in February 2021, which reshaped what variable and index products are available to whom and under what conditions. This guide covers the full landscape of variable and index rate commercial electricity plans in Texas: how they work, who they make sense for, the risks, the regulatory framework, and the hybrid structures that have become the dominant way sophisticated commercial buyers manage wholesale market exposure. What Is an Index Rate Electricity Plan An index rate plan ties your energy charge directly to a published wholesale market price index, plus a fixed adder (sometimes called a "heat rate" or "margin") charged by your REP . The formula looks like this:  Your Energy Charge = Wholesale Index Price + REP Adder For example, if your contract is indexed to the ERCOT day-ahead Houston hub price and your REP charges a $4.50/MWh adder, your energy charge for each hour is the published day-ahead Houston price for that hour plus $4.50/MWh. If day-ahead Houston was $35/MWh on a mild spring day, your rate for that hour is $39.50/MWh. If day-ahead Houston was $450/MWh during a summer afternoon, your rate for that hour is $454.50/MWh. The critical feature is transparency. Because the index is a publicly published wholesale market price, you can verify every hour of your bill against ERCOT's published data. The REP cannot unilaterally change your rate — only the adder and the settlement methodology are contractual, and the index itself is set by the market.