The instinct that "fixed is safe, variable is risky" survives in Texas commercial electricity procurement mostly because nobody paid to sell you a contract has an interest in complicating it. Fixed-rate contracts have real risks that don't show up until year two. Indexed contracts have structural advantages that most commercial buyers never hear about. The right question isn't "fixed or indexed?" It's "what does my load look like, what's my risk tolerance actually constrained by, and where does the ERCOT curve sit right now?"
This is the guide that walks through fixed vs indexed electricity contracts in Texas from the perspective of a supplier-neutral advisor rather than a REP with a quota. It covers what each product structure actually is (including the hybrids most brokers won't offer smaller accounts), how they performed through the 2024-2025 ERCOT price environment, and a decision framework that goes beyond the marketing binary.
The Three Product Families (Not Two)
Almost every commercial electricity discussion frames the decision as fixed versus variable. That's a false binary. Texas commercial buyers have three functional product families available, and lumping the middle one into "variable" hides the option that fits most mid-market businesses best.
Fixed-rate contracts
The energy portion of your bill is locked at a specific ¢/kWh rate for the contract term. Every kWh delivered during the term is billed at that rate regardless of what happens in the wholesale ERCOT market. Contract terms typically run 12, 24, or 36 months.
What fixed actually protects: your energy cost per kWh from wholesale market swings.
What fixed does not protect: TDSP delivery rate changes (which happen twice yearly on regulated tariffs), tax changes, pass-through riders your contract explicitly permits, and the impact of your own usage variability on your effective rate.
Indexed contracts
The energy portion of your bill floats with a specified wholesale market index, typically the ERCOT day-ahead or real-time settlement point price at your load zone, plus a defined per-kWh adder that covers the REP's margin and operating costs. Every month reflects wholesale market conditions during that month.
What indexed offers: direct exposure to wholesale market conditions in both directions. When prices are low, you pay less. When they spike, you pay more.
What indexed requires: financial capacity to absorb monthly bill volatility, and some operational awareness of when to reduce load during high-price intervals.
Hybrid or block-and-index contracts
A defined portion of expected load is priced at a locked block rate; the remainder is priced at the index. The customer captures some price certainty on the block and some market flexibility on the index tail.
Hybrid products used to be reserved for industrial buyers above 1,000 kW. Since 2023, several Texas REPs have started offering them to accounts as small as 250 kW peak demand, and the operational math often works. For a full walkthrough of the product family, see our guide to block-and-index and hybrid energy products for Texas commercial buyers.
What "Safe" Actually Means for a Fixed Contract
The pitch for fixed-rate contracts is simple: predictability. Your energy cost is known. Budgets are stable. Nothing surprises you. That pitch is technically accurate but functionally misleading, because it hides three risks that fixed contracts create.
Risk 1: Locking at market peaks
A fixed contract signed at a bad moment in the ERCOT forward curve commits you to that pricing for the entire term. If the market softens six months later, you keep paying above-market rates for the remaining 18 to 30 months. The buyer who locked a 36-month contract in July 2022 (near the top of that year's summer forward curve) paid meaningfully more than the buyer who locked the same product six months later, and the gap compounded across the term.
The "safety" of a fixed rate assumes you signed at a reasonable point on the curve. If you didn't, that safety is expensive.
Risk 2: Early termination fees
Fixed contracts almost always include early termination fees (ETFs) that make it costly or impossible to exit if market conditions change or your business situation shifts. For contracts with make-whole ETF structures, the exit cost can approach the entire remaining value of the contract, effectively locking you in regardless of market movements. Our guide to early termination fees on Texas commercial electricity contracts covers the calculation methodologies.
Risk 3: The holdover cliff at expiration
At the end of a fixed contract, the customer either signs a new contract or transitions to holdover pricing that commonly runs 2 to 3 times the expired rate. Fixed-rate customers who miss the renewal window face sharp cost increases that pure indexed customers, ironically, never experience because indexed customers never had a "contract expiration" event in the same sense. Our guide on holdover rates in Texas commercial electricity covers this in depth.
None of these risks are reasons to avoid fixed contracts. They're reasons to enter fixed contracts with the same discipline you'd bring to any other multi-year financial commitment.
What "Risky" Actually Means for an Indexed Contract
The pitch against indexed contracts is equally simple: volatility. Your bill goes up and down. You never know what you'll pay. During a Winter Storm Uri event, indexed customers received bills that made regional news. That pitch is also technically accurate but functionally misleading, because it hides two features that make indexed contracts structurally attractive for certain buyers.
Feature 1: Direct capture of favorable wholesale conditions
ERCOT wholesale prices during typical mild weather periods, high wind production, or shoulder seasons frequently trade well below the equivalent retail fixed rates. Indexed customers see this directly on their bill. Fixed customers pay the same rate whether wholesale prices are $28/MWh or $58/MWh.
Across 2024, ERCOT wholesale settlement prices averaged in the mid-30stolow-40s per MWh for much of the year outside of summer peak weeks. Indexed customers with typical retail adders (roughly $8 to $15/MWh) paid effective supply rates in the $45 to $55/MWh range for those months. Fixed-rate customers on 24-month contracts locked in early 2023 were paying $60 to $75/MWh for the same months. The difference across 12 months on a 30,000 kWh account approached $5,000 to $8,000.
Feature 2: No renewal cliff
An indexed contract doesn't "expire" in the same way a fixed contract does. Most indexed contracts run month-to-month or annually with no substantial change in pricing methodology at renewal. There's no holdover cliff, no forced re-shopping, no missed renewal notice producing a 2.5x rate jump. The customer's exposure is continuous rather than concentrated at renewal dates.
The trade-off, of course, is real: indexed customers absorb wholesale volatility during high-price events. Whether that trade-off works depends on the customer's specific profile.
How 2024 and 2025 Tested Both Structures
The two-year period ending Q2 2026 gave Texas commercial buyers unusually clear data on how fixed and indexed structures performed under real conditions.
2024: Favorable to indexed structures
The ERCOT wholesale market in 2024 was characterized by high renewable generation output, generally moderate weather (with the notable exception of extreme heat in July and August), and below-average natural gas prices. Wholesale settlement prices trended lower than most 2023 fixed-contract quotes had priced in.
Result: indexed customers who signed in late 2023 or early 2024 typically paid meaningfully less on the energy portion than fixed-rate customers on 24-month contracts signed at the same time.
Q3 2024: The tail-risk reminder
An unusually intense heat dome in late July and early August produced multi-week wholesale price elevation in ERCOT, with day-ahead prices frequently trading above $200/MWh and real-time prices spiking above $1,000/MWh during specific afternoons. Indexed customers received bills reflecting those spikes. Fixed customers didn't feel it.
The event confirmed what indexed buyers already know: pure indexed exposure carries real event risk that fixed contracts hedge away. But it also confirmed that a well-structured hybrid (with a substantial block portion covering base load) absorbs most of the event risk while still capturing normal-month savings on the index tail.
2025: Moderate winter, mixed summer
2025 winter conditions were generally moderate compared to 2021's Winter Storm Uri. ERCOT completed additional reliability investments through 2024 and early 2025. Wholesale prices trended lower than fixed-contract quotes from mid-2023 had priced in for most of Q1 and Q2 2025.
Summer 2025 was neither as extreme as 2024's July-August event nor as mild as some forecasts had suggested. Indexed customers had a mixed year: some months of clear savings vs fixed, one or two months of elevated cost.
Averaged across the full 24 months from mid-2023 through mid-2025, well-structured hybrid contracts (typically 60% to 70% block, remainder indexed) generally outperformed both pure fixed and pure indexed for customers with appropriate load profiles. This is not universally true (specific customers with specific load shapes had different outcomes), but it's the general pattern.
The Load Factor Question That Changes Everything
The first question that should inform your fixed-vs-indexed decision has nothing to do with market forecasts and everything to do with your own operations: what's your load factor, and how consistent is it month to month?
High load factor businesses (65% and above) have relatively predictable, steady electricity consumption. Continuous manufacturing, cold storage, data centers, telecom hubs, and 24/7 operations fall here. These businesses have several attributes that make hybrid or indexed structures attractive: predictable base load that can be hedged in blocks, operational stability that supports absorbing month-to-month variability, and enough total spend to justify the additional contract complexity.
Moderate load factor businesses (40% to 65%) have meaningful daily and weekly variation but broadly consistent patterns. Most office-based businesses, retail chains, hotels, warehouses with day-shift operations, and healthcare facilities fall here. Standard fixed-rate contracts typically fit these buyers well. Hybrid structures can work for larger buyers in this range but often don't justify the added complexity.
Low load factor businesses (below 40%) have sharp, unpredictable peaks separated by low-usage periods. Restaurants, schools, churches, event venues, and seasonal operations fall here. Fixed contracts are almost always the right structure. Indexed and hybrid products depend on some ability to hedge base load, which low-LF businesses don't reliably have.
For a full walkthrough of load factor as a procurement input, our guide on load factor for Texas commercial electricity rates covers the calculation and its impact.
The Decision Framework: Five Inputs
The right product structure for a specific Texas commercial buyer emerges from five inputs, none of which alone is decisive but which collectively point to a reasonable answer.
Input 1: Peak demand
Below roughly 100 kW peak demand: fixed contracts almost always fit best. The absolute dollar impact of alternative structures rarely justifies their complexity.
Between 100 and 500 kW: fixed contracts fit most buyers, but hybrids become viable if the business also fits other criteria below.
Above 500 kW: all three structures deserve real evaluation. The dollar stakes are meaningful enough that generic advice becomes expensive.
Input 2: Load factor
Above 65%: indexed and hybrid become structurally attractive.
Between 40% and 65%: fixed generally fits, hybrid may add value for larger accounts.
Below 40%: fixed is almost always right.
Input 3: Financial capacity to absorb volatility
If a 40% monthly bill increase during an extreme wholesale event would create a cash flow crisis, you cannot take direct indexed exposure. Full stop. A well-structured hybrid with a large block portion may still work, but the risk envelope must fit the balance sheet.
If your business can absorb such an event without operational impact (larger balance sheet, diversified revenue, low variable-cost sensitivity), indexed exposure becomes a defensible risk.
Input 4: Operational engagement capability
Indexed and hybrid products reward active management. Someone (in-house, consultant, or the REP itself) needs to monitor wholesale conditions, add block coverage opportunistically when favorable pricing appears, and possibly reduce load during high-price events.
Fixed contracts require no ongoing engagement beyond eventual renewal. If nobody at your business is going to spend time on electricity procurement between contract signing and renewal, indexed and hybrid products won't deliver their potential advantages.
Input 5: Current position on the ERCOT forward curve
If the current forward curve for your desired term is trading at multi-year highs (relative to typical historical levels for the delivery period), long fixed contracts are less attractive than they'd otherwise be. Shorter fixed terms or hybrid structures with delayed block additions can help.
If the current forward curve is trading at multi-year lows, longer fixed terms become more attractive because you're capturing favorable pricing for extended periods.
This input isn't about market timing in a speculative sense. It's about the observable current state of the market, which affects the value proposition of each product structure.
Product Structure by Business Type
The most useful framing isn't a matrix showing "if X then Y." It's a set of representative business profiles and the product structure that typically fits each.
The restaurant with three locations, all under 50 kW
Low load factor, small scale, no operational bandwidth for market monitoring. Fixed 24-month contracts across all three sites, ideally with a portfolio-level RFP to negotiate consistent pricing. Indexed and hybrid are not appropriate here.
The distribution warehouse with 400 kW peak demand, single site
Moderate load factor, mid-scale, stable operations. Fixed 24-month contract fits well. If the buyer has some engagement capacity and financial cushion, a hybrid with a modest block-to-index split (75/25) could work but is not necessary.
The manufacturing plant with 1,500 kW peak demand and 24/7 operations
High load factor, large scale, stable operations, likely has some in-house energy awareness. Strong candidate for hybrid (65/35 or 70/30 block-to-index typical). Pure fixed still viable for buyers with lower risk tolerance. Pure indexed rarely appropriate outside of very sophisticated operations.
The cold storage operator with 800 kW peak demand and multi-site portfolio
High load factor, stable base load, portfolio-level considerations. Strong hybrid candidate at portfolio level, with the block sized against aggregate base load across sites. Our guide to warehouse and cold storage electricity procurement in Texas covers the sector specifics.
The data center with 3 MW peak demand and continuous operation
Very high load factor, meaningful scale, sophisticated operations. Hybrid becomes attractive with substantial block coverage. Some data center operators run pure indexed positions because they have direct visibility into wholesale market conditions and can respond during high-price events. Peak shaving with battery storage during 4CP intervals adds substantial value.
The 12-location retail chain across multiple TDSPs
Moderate load factor at each site, varying scale. Portfolio-level fixed contract typically fits. Aggregation across sites can produce pricing improvements even without changing the product structure. Our guide to multi-site energy procurement for Texas businesses covers portfolio aggregation.
The medical office building or clinic
Moderate load factor, small-to-mid scale, low operational bandwidth. Fixed 24-month contract fits well. Focus on getting competitive pricing rather than product structure optimization.
Why Fixed Contracts Dominate Mid-Market Texas
Look at the actual distribution of contracts signed by mid-market Texas commercial buyers between 2020 and 2025, and fixed-rate contracts substantially outnumber indexed and hybrid combined. This isn't because fixed is objectively better for all these buyers. It's because:
Sales incentives favor fixed: REP salespeople and brokers are typically compensated for signing fixed contracts. Indexed and hybrid products require more explanation, longer sales cycles, and often produce less commission.
Buyers default to what feels familiar: Fixed-rate contracts resemble other business commitments buyers understand: fixed pricing for a term, with a defined end date. Indexed and hybrid feel more exotic.
Bad experiences get amplified: The Winter Storm Uri event in February 2021 produced widely-publicized bills for indexed customers that made "never touch indexed" the default reaction for years afterward. The bills were real; the reaction was, arguably, overblown for typical operating conditions.
Brokers rarely offer hybrids to mid-market buyers: Even where a hybrid would fit, many brokers don't quote them because their supplier relationships and internal comp structures don't support it.
If you're a mid-market Texas commercial buyer who was told "we only offer fixed" or was steered away from indexed and hybrid options without a specific reason tied to your operations, you may not have been given the full option set. Supplier-neutral procurement, by definition, evaluates all three families against your specific profile.
What a Fair Comparison Actually Looks Like
If you're evaluating fixed versus indexed (or hybrid) offers side by side, comparing the headline ¢/kWh rates alone will mislead you every time. The two products aren't measuring the same thing. Fixed shows a locked rate; indexed shows an adder over a floating market price. They can't be compared as apples to apples.
The methodology that works:
Step 1: Compile 12 to 24 months of your historical hourly load data.
Step 2: Apply the fixed contract rate to that historical load. Multiply your hourly kWh by the fixed rate. Sum by month. This gives you what your energy cost would have been under the fixed contract, historically.
Step 3: Apply the indexed adder plus the actual historical ERCOT settlement prices to the same historical load. For each hour, multiply the hourly kWh by (settlement price + adder). Sum by month. This gives you what your energy cost would have been under the indexed contract during the same historical period.
Step 4: Compare month by month, and total.
This exercise typically shows:
- Indexed produces lower total costs across most 12-month backward-looking windows.
- Fixed produces smoother month-to-month costs (lower standard deviation).
- Certain months (usually July-August) favor fixed; certain months (usually shoulder seasons) favor indexed.
- Hybrid structures produce total costs between the two, with volatility profile between the two.
Important caveat: history is not prediction. The next 24 months will not perfectly resemble the last 24 months. This exercise reveals the pricing dynamics of each structure against realistic load patterns; it doesn't tell you the winner going forward.
Where Indexed Goes Wrong
For buyers who did choose indexed structures and had bad outcomes, the failure modes are consistent.
Indexed without sufficient block coverage during extreme events: A pure indexed position or a hybrid with too little block coverage leaves the customer directly exposed during Uri-scale events. Well-structured hybrids can absorb most of the tail risk.
Signing during a period of unusually low wholesale prices: Indexed contracts signed when the ERCOT market looks cheap can produce unpleasant reversal when wholesale prices normalize. The adder over settlement is what you're really buying; low current settlement prices don't help if the market repositions upward.
No operational engagement: Buyers who sign indexed contracts and treat them like fixed contracts (ignore them until renewal) miss most of the potential value and get surprised by unfavorable months.
Wrong index selection: Some indexed contracts price against ERCOT hubs; others against specific settlement points at the customer's location. During transmission-constrained periods, these can diverge substantially. Understand which index applies to your contract.
Where Fixed Goes Wrong
Fixed contracts fail buyers in equally predictable ways.
Signing near forward-curve peaks: Locking a 24-month contract when the market is elevated commits the buyer to that pricing whether or not conditions normalize. Buyers who signed in mid-2022 during the natural gas price spike paid meaningfully above-market for 24+ months.
Not shopping the renewal: Signing a fixed contract and then accepting whatever the incumbent quotes at renewal produces above-market pricing over time.
Ignoring pass-throughs: Fixed contracts protect the energy rate but usually don't protect against pass-through changes (TDSP rate adjustments, some rider changes, certain ancillary services). A fixed contract can still see meaningful bill movement from these components.
Poor ETF and bandwidth clauses: Fixed contracts with punitive ETFs or narrow bandwidth clauses trap the buyer when operations change. Our guides on ETFs and bandwidth and swing clauses in commercial energy contracts cover the specific mechanisms.
The Most Common Answer for Mid-Market Texas Businesses
For most Texas commercial buyers between 50 and 500 kW peak demand, on standard operating profiles, the right answer remains a well-structured fixed-rate contract signed during a reasonable point on the ERCOT curve, with 24-month term, transparent pass-through provisions, and reasonable ETF and bandwidth clauses.
The path to a better outcome isn't necessarily switching to indexed or hybrid. It's:
- Signing at a defensible point on the curve rather than at whatever moment the incumbent's renewal notice arrives
- Running a competitive RFP rather than accepting the first quote
- Redlining bad contract terms rather than accepting standard templates
- Tracking renewal dates and starting the next cycle 6+ months in advance
Product structure optimization becomes valuable at 500 kW and above, where the absolute dollar stakes justify the added complexity of hybrid structures and the operational engagement they require.
Frequently Asked Questions
Should my Texas business choose fixed or indexed electricity?
For most small and mid-sized Texas commercial businesses (below 500 kW peak demand), a fixed-rate contract fits best. It provides budget predictability, requires no ongoing market engagement, and matches the operational profile of typical office, retail, restaurant, and light-manufacturing businesses. Larger businesses with continuous operations, high load factors, and financial capacity to absorb month-to-month variability should evaluate hybrid (block-and-index) structures, which have historically produced lower total costs than pure fixed for customers with appropriate profiles.
When is an indexed rate better than fixed for a business?
Indexed rates tend to outperform fixed rates in periods of moderate weather and healthy renewable generation output, which characterizes much of the year in ERCOT outside of summer peak weeks. The 2024 calendar year, for example, saw indexed customers pay meaningfully less than fixed-rate customers on 24-month contracts signed in early 2023. However, indexed customers are directly exposed to extreme events (heat waves, cold snaps, generation shortages), which can produce sharp cost increases. The trade-off is more favorable for customers with financial capacity to absorb volatility and operational capability to manage the position.
What is the difference between fixed and variable commercial electricity rates in Texas?
A fixed rate locks the energy portion of your bill at a specific ¢/kWh for the entire contract term. A variable (or indexed) rate floats with the wholesale ERCOT market plus a defined adder, changing month to month based on wholesale conditions. Fixed provides budget predictability but no ability to capture favorable market conditions; indexed captures market movements in both directions but requires financial capacity to absorb volatility. A third option, block-and-index or hybrid, combines both: a fixed block covers part of the load, and the remainder floats with the market.
What is a hybrid or block-and-index electricity contract?
A hybrid contract divides expected load into two portions. A specified percentage (typically 50% to 80%) is priced at a locked block rate for the contract term. The remainder is priced at the wholesale ERCOT index plus a defined per-kWh adder. This structure captures some price certainty on the block while retaining some ability to benefit from favorable wholesale market conditions on the index tail. Hybrids used to be reserved for industrial customers, but several Texas REPs now offer them to accounts as small as 250 kW peak demand.
How did indexed contracts perform through 2024 and 2025 in Texas?
2024 was generally favorable to indexed structures: high renewable output, moderate weather (with the notable exception of extreme heat in July and August), and below-average natural gas prices produced wholesale settlement prices that trended below typical fixed-contract quotes from 2023. Indexed customers who signed in late 2023 or early 2024 typically paid meaningfully less than fixed customers on comparable terms. 2025 was more mixed, with moderate winter and mixed summer conditions. Averaged across 24 months, well-structured hybrid contracts generally outperformed both pure fixed and pure indexed for customers with appropriate load profiles.
Can I switch from a fixed contract to indexed mid-term?
Not without paying an early termination fee. Fixed contracts almost always include ETFs that make mid-term exits costly, and switching to a different product with the same or different REP requires exiting the current contract. The typical path is to fulfill the current fixed contract to expiration and then choose a different structure for the next term. If market conditions have shifted substantially and the ETF is small enough, the switch math can work; usually it doesn't.
Are indexed contracts still dangerous after Winter Storm Uri?
Uri in February 2021 was a specific and extreme event where ERCOT hit its previous $9,000/MWh price cap for extended periods. That cap has since been reduced to $5,000/MWh, and Texas has invested substantially in grid reliability infrastructure through 2024 and 2025. Extreme events remain possible, but the tail risk profile is different than in 2021. Well-structured hybrid contracts with substantial block coverage now provide a middle path that absorbs most extreme-event risk while capturing normal-month indexed savings. Pure indexed positions still carry meaningful event risk and require both financial cushion and active management.
What is the ERCOT forward curve?
The ERCOT forward curve is the set of wholesale electricity prices at which market participants can currently buy or sell energy for future delivery periods in Texas. It's continuously traded and moves daily based on natural gas prices, weather forecasts, generation resource adequacy, and market positioning. Retail commercial contract rates are priced against the current forward curve at the time of signing. For a more comprehensive overview of ERCOT market mechanics, see our guide on ERCOT and how Texas electricity is priced.
How much can hybrid contracts save vs. fixed?
Historically, hybrid structures with 60% to 75% block coverage have saved Texas commercial customers with appropriate load profiles 5% to 12% on average energy costs vs. comparable fixed contracts over 24-month terms. Individual results vary based on specific load profiles, block sizing, market conditions during the term, and the specific index used for the tail. Extreme events can compress or reverse these savings for specific months, but the multi-year averages have generally favored well-structured hybrids for customers who fit the profile.
What is a heat rate and why does it matter for indexed contracts?
Heat rate is the ratio of natural gas price to electricity price, expressed as MMBtu/MWh. It matters because natural gas is the marginal fuel for much Texas generation, so heat rates influence when generators enter or leave the market and therefore where wholesale prices settle. Indexed customers with sophisticated market monitoring watch heat rates alongside other metrics to identify favorable moments to add block coverage or reduce load. For most mid-market indexed customers, this level of engagement is unnecessary; general awareness of market direction is sufficient.
Does load factor matter for the fixed vs indexed decision?
Yes, substantially. High load factor businesses (65%+) have predictable base load that can be hedged efficiently in block products, making hybrid structures naturally attractive. Low load factor businesses (below 40%) have sharp, unpredictable peaks that don't align well with block products; fixed contracts fit these buyers better. Our guide on load factor for Texas commercial electricity rates walks through the calculation and its impact on product structure decisions.
What's the worst case for indexed customers in a bad month?
During Winter Storm Uri in February 2021, some indexed customers received monthly bills 20 to 50 times their normal levels. The wholesale price cap was $9,000/MWh at the time; it has since been reduced to $5,000/MWh. Even at the current cap, an extreme multi-day event could still produce monthly bills 5 to 15 times normal levels for pure indexed customers. Well-structured hybrid contracts with substantial block coverage and specific cap protections can reduce this worst-case scenario meaningfully, but not eliminate it entirely.
Should a first-time commercial buyer choose indexed?
Generally no. First-time commercial energy buyers typically benefit from the operational simplicity of a fixed contract while learning how their bill actually works, how the market moves, and what pass-through mechanisms affect their costs. After a full contract cycle (typically 24 months), buyers have the context to evaluate alternative structures for their next term. Jumping straight to indexed or hybrid without that foundation often produces buyer's remorse the first time a volatile month arrives.
Are there hybrid contracts for smaller businesses (under 250 kW)?
Historically no, but the market has evolved. Since 2023, several Texas REPs have offered scaled-down block-and-index structures for accounts as small as 100 kW peak demand. Whether these work for smaller buyers depends on the specific product structure, the adders, and whether the buyer has any operational engagement capacity. For most buyers under 250 kW, the added complexity outweighs the potential savings, but the option now exists where it didn't five years ago.
What role does the ETF play in the fixed vs indexed decision?
ETFs matter because they determine your flexibility if conditions change. A fixed contract with a punitive make-whole ETF locks you in regardless of what happens to markets or your business. An indexed contract with a modest exit fee (or none) preserves optionality. If you're choosing between comparable products with very different ETF structures, the more flexible ETF has value beyond just the energy price. Our detailed guide on early termination fees in Texas commercial electricity covers the specific structures and their implications.
Making the Fixed vs Indexed Decision
If you're evaluating a fixed vs indexed decision for your Texas business right now:
Start with your load profile: Pull 12 to 24 months of billing data, calculate your monthly load factor, identify your base load vs. peak load, and understand your usage variability. This determines which product structures are viable.
Test both structures against historical data: Apply the fixed rate quote to your historical load. Apply the indexed adder plus historical ERCOT settlement prices to the same load. Compare month-by-month and total. This shows you how each structure would have performed, historically, on your actual usage.
Assess your risk envelope: Determine the largest monthly bill increase your business can absorb without operational impact. That number defines whether indexed exposure is viable at all, and how large a block portion a hybrid needs.
Get quotes for all three structures if you're above 500 kW: Below 500 kW, focus on getting competitive fixed quotes. Above 500 kW, request fixed, indexed, and hybrid quotes from multiple REPs on identical specifications and compare across all three.
Don't optimize product structure without also optimizing timing: Signing an "optimal" product structure at a bad point in the ERCOT curve produces worse outcomes than signing a suboptimal structure at a good point. Timing matters as much as product choice.
Electric Decisions runs supplier-neutral procurement for Texas commercial buyers across all three product families. We evaluate fixed, indexed, and hybrid options against each buyer's specific profile, benchmark quotes against the live ERCOT forward curve, and disclose all pricing components fully. Our 5-step energy procurement process for Texas commercial buyers applies whether the eventual answer is a straightforward fixed contract or a customized hybrid structure.
For larger buyers evaluating the hybrid alternative, our block-and-index and hybrid energy products guide walks through the structural options in more depth.
The right answer to fixed versus indexed isn't universal. It's specific to your load, your balance sheet, your operational capacity, and where the ERCOT curve sits when you sign. What is universal is the value of running that analysis before signing, rather than accepting whatever product the first broker in your inbox happened to want to sell you.
