• Risk visibility has become more challenging despite energy trading data integration
• Faster or larger volumes of data can inhibit risk visibility in power markets
• Data quality determines whether risk teams can act with confidence when markets move

As power markets become more volatile and interconnected, data quality increasingly determines whether risk views hold up under pressure. While “more is better” may apply to trading data, more data can hinder risk management when it is not structured for decision-making, requiring hours of manual reconciliation and delaying intraday responses.

When risk data is not accurate, clearly defined, and delivered at the right cadence, risk teams hesitate to rely on it without validation. When traders ask questions, risk must pause to reconcile definitions, timing, and assumptions before responding — delaying decisions and eroding confidence.

Table of Contents

1. Market Change Is Stressing Data Environments
2. Integrated Data Can Inhibit Risk Visibility
3. Faster Data Can Create a False Sense of Control
4. Reconciliation: The Hidden Cost of Inconsistent Data
5. When Risk Confidence Breaks
6. What Good Data Looks Like in Power Trading Risk Management
7. Focus on Data Quality Over Quantity
8. Frequently Asked Questions

Market Change Is Stressing Data Environments

Changes to both supply and demand are adding complexity to power market data environments, straining risk data and stressing risk management systems.

New sources of renewable energy change the shape, timing, and uncertainty of market fundamentals. Traditional models were built for slower, more predictable systems. Intermittent renewables introduce intraday shifts in output and localized congestion that stress data definitions, hierarchies, and timing conventions.

Renewable buildout is often geographically concentrated, amplifying congestion and basis volatility at specific nodes or zones. As a result, data that is not granular enough (zonal versus nodal) will miss localized grid congestion caused by renewable energy supply. Renewable data arrives from more sources (weather vendors, ISO feeds, asset telemetry), each with different cadences and semantics, increasing timing and interpretation mismatches across systems.

On the demand side, new power-hungry data centers generate faster, more localized shifts in load, generation, and congestion, creating gaps between real-time price signals and the exposures reflected in risk reports. Zonal aggregation and static hierarchies can obscure emerging nodal congestion, creating gaps between market prices and modeled exposure. At the same time, forecasts and risk snapshots lag behind real-time prices, creating temporal blind spots, so the system appears balanced while structural conditions have already shifted.

This can play out in environments where new commodity exposure was introduced faster than reporting structures could adapt. Risk policies were updated, hedges were layered in, and exposure profiles changed, but the underlying data pipelines still reflected an earlier operating model. The risk views were technically integrated, but structurally behind the business they were meant to represent.

While near-real-time data provides a current view of power grids, speed alone does not create confidence in risk workflows. Data can move faster through pipelines, but if assumptions, semantics, or timing conventions differ across systems, risk views diverge precisely when alignment matters most.

Integrated Data Can Inhibit Risk Visibility

In the push to automate, integrate, and take advantage of real-time data, energy trading data integration has focused on moving data quickly, sometimes missing the essential step of aligning meaning, timing, or decision context. As more platforms are connected, inconsistencies in timing, granularity, and assumptions propagate faster, amplifying noise instead of improving clarity. In this case, speeding data up can actually make risk visibility slower and more challenging.

More systems are connected, more data flows, and updates arrive more frequently, but without shared semantics. “Exposure,” “position,” “load,” or even the most basic terms like “today” can mean different things in different systems. The result is apparent completeness with hidden disagreement, so systems are synchronized but not aligned, forcing risk managers to determine which system reflects economic reality. When risk teams cannot explain how a number changed between the source and the final report, that disagreement erodes confidence.

Timing mismatches also create alignment challenges. Market prices, grid conditions, and load signals move intraday, while many risk systems still aggregate on end-of-day or batch cycles. Congestion, weather, or concentrated load can reprice specific nodes or hours immediately, but risk systems are still using data that is hours behind. Integrated systems faithfully pass forecasts and positions downstream, even when underlying assumptions have already been invalidated by localized market signals, creating confidence based on stale alignment.

Risk visibility suffers when systems are tightly connected but loosely aligned to how markets actually move. Each downstream correction becomes manual, reactive, and judgment-based, shifting effort from risk insight to data repair and weakening confidence in reported positions.

Faster Data Can Create a False Sense of Control

Continuous updates create an illusion of control. When numbers refresh smoothly, users infer stability even when the market has shifted outside modeled conditions. Data can be fast and still arrive too early, too late, or at the wrong granularity for how risk decisions are made. If definitions, hierarchies, or effective dates differ, faster data simply increases noise, forcing more reconciliations and eroding confidence.

Speed alone does not fix this. While data velocity and volume increase activity, confidence in risk numbers only increases when data is structured, semantically aligned, and explicitly tied to where and when risk decisions are made. Confidence comes from alignment with margin calls, trading limits, and intraday actions, not just speed. Faster data does not help risk management if forecasts, sensitivities, or correlations cannot adapt to localized stress or shifting market conditions.

Reconciliation: The Hidden Cost of Inconsistent Data

While some reconciliation is required to maintain control of risk systems, when reconciliation becomes constant or structural, it signals deeper misalignment and shows that data is not risk-ready. Risk teams absorb the cost through manual checks, overrides, and judgment calls that grow with market volatility, portfolio complexity, and operational change. In some environments, this looks like hours spent each morning reconciling exposures before risk teams feel comfortable publishing a number.

Reconciliation undermines intraday confidence by forcing teams to debate which number is correct before they can assess what risk actually looks like. Decisions are delayed while exposures remain provisional, subject to revision as data catches up. When positions are perpetually under review, risk insight becomes retrospective—explaining yesterday’s inconsistencies rather than informing today’s actions—leaving teams reactive at precisely the moments when clarity, and decision speed, matter most.

That is the irony of more, faster data. Faster “bad” data actually slows the entire process down, inhibiting risk visibility while time is spent determining which data is correct in the flood of data feeds and reconciling data across all systems.

When Risk Confidence Breaks

Risk confidence doesn’t fail gradually in power markets. It breaks at specific moments when the numbers stop supporting decisions. That pattern extends beyond energy trading, with 72% of business leaders reporting that the combination of data volume and low trust in data has prevented them from making decisions at all.

That break often starts intraday, when prices move materially but positions remain unchanged because forecasts, shapes, or nominations have not yet updated, leaving reported positions artificially stable. The trading desk sees volatility when risk sees stability, and that gap creates the first crack in risk confidence.

As volatility intensifies, the distortion deepens during congestion or scarcity events. Nodal prices diverge sharply while exposures remain aggregated at hub or zone level. Risk reports show diversification benefits that no longer exist once the grid binds. What appears hedged in one view no longer matches how the market is actually moving.

By the end of the operating day, the strain compounds. Trades executed late, reshaped, or reclassified flow through systems with mismatched effective dates. Risk appears flat until the next run, at which point yesterday’s assumptions are reversed. The exposure shift is driven not by a new decision, but by timing and alignment gaps across systems.

By the time margin or credit conversations begin, confidence is already fragile: the exposure jump cannot be explained cleanly because the answer requires untangling timing lags, late trade feeds, and forecast roll-forwards that accumulated across the operating day.

What Good Data Looks Like in Power Trading Risk Management

When manual controls become the norm — with finance teams spending roughly 25–30% of their time on manual, automatable tasks — risk confidence breaks and risk management becomes retrospective, accurate once corrected but decisive too late. In modern power markets, better data is more than just real-time feeds or higher resolution data.

• Data arrives at the cadence at which risk must act. Data only needs to be real-time if risk can react in real time, or intraday when prices, congestion, or margin can move materially.
• Positions, load, congestion, and exposure roll up the same way everywhere, so exposure does not appear diversified in one system and concentrated in another.
• Key concepts — effective date, exposure, forecast, mark, limit — have enforced definitions, so exposure does not shift simply because systems interpret time or scope differently.
• Data is captured granularly instead of averaged away, highlighting where small physical changes can cause large financial impacts.
• Data is shaped around how risk is managed: limits, margin, liquidity, intraday hedging, and executive questions. If it does not answer the right questions, it is not useful.

Better data surfaces where assumptions may be breaking, such as forecast divergence, price–load mismatches, or conditions outside historical ranges. It aligns meaning, timing, and market behavior, so that when conditions change quickly, risk managers see where risk confidence should degrade before P&L forces the lesson.

Focus on Data Quality Over Quantity

The common thread in these environments is not a lack of integration, nor a lack of technology investment. It is a gap between how markets move and how systems reconcile. When that gap widens — even temporarily — risk teams shift from analyzing exposure to defending numbers.

Risk teams are surrounded by data feeds (prices, load forecasts, outages, weather, etc.), yet risk confidence depends on that data being fit for decision, not merely available. Quality data is timely enough to matter, consistent enough to compare, and aligned enough to explain. When data quality in power trading breaks down, adding more data increases reconciliation, interpretation, and judgment, slowing the process down exactly when decisions need to be made quickly, and with confidence.

In power markets, effective risk management requires having data you trust when the grid tightens, prices move, and decisions cannot wait. When the number holds up under scrutiny, risk teams can act decisively — even as markets tighten and exposure shifts.

Frequently Asked Questions

In modern power trading environments, risk doesn’t always break because data is missing or delayed. More often, it breaks because the same trade is understood differently as it moves between systems.

Key Takeaways

1. Energy trading data comes from many disparate systems, and collecting, sharing, and using this data consistently is critical
2. Data challenges undermine risk visibility, increasing exposure
3. When systems drift out of alignment, risk blind spots emerge

Risk views drift when the same position is interpreted differently across systems. In power and renewables trading, that misalignment shows up more often as portfolios grow and workflows span multiple platforms.

A trade can appear live in the front office while downstream systems apply different assumptions about timing, settlement, or delivery mechanics.

When that happens, teams spend time reconciling gaps, explaining unexpected P&L movements, or double-checking whether today’s exposure actually reflects reality — even though the underlying data arrived on time.

In this context, “API maturity” isn’t about technology sophistication. It’s about whether systems enforce a shared understanding of trades, timing, and market data as information moves between trading, scheduling, and risk – or whether that meaning quietly drifts as data flows downstream.

Table of Contents

1. Why System Drift Gets Worse as Power Portfolios Scale
2. Interoperability Data Challenges
3. Risks From Data Inconsistency
4. Mature APIs in Energy Trading
5. Benefits of API Maturity
6. How To Determine If Your Integration Architecture Can Scale
7. Why Shared Meaning Matters

Why System Drift Gets Worse as Power Portfolios Scale

As power portfolios expand into intraday markets, certificates, and cross-border portfolios, more systems feed into a single risk view. Each new integration introduces another place where timing and definitions must stay aligned. The larger the portfolio, the smaller the margin for interpretation errors.

In power markets, operational events — like congestion, curtailments, or outages — directly affect positions and exposure, and those events need to propagate consistently across trading and risk systems. When they don’t, exposure and P&L can shift based on interpretation rather than market reality.

This is where API maturity shows up in practice. Interoperability breaks down not because systems can’t connect, but because the connections between them don’t consistently enforce shared meaning and timing. When that enforcement breaks down, risk leaders are left reconciling numbers instead of acting on them.

API maturity shows up in how systems stay aligned as data moves, or whether trades, timing, and definitions quietly drift apart across trading and risk.

With data aggregating from different sources, mature APIs ensure that systems are not just connected, but that they receive the same data, defined the same way. Without that consistency, risk gets managed based on assumptions inside each system, not the actual market events.

In practice, API maturity allows trading, scheduling, and risk systems to operate as a coherent ecosystem rather than isolated silos. When systems share a common understanding of trades and timing, positions and exposure update predictably, so teams work from the same view of risk instead of reconciling conflicting numbers after the fact.

For risk owners, this alignment is what makes it possible to answer basic questions quickly: whether today’s exposure reflects reality, or whether teams are still reconciling yesterday’s numbers.

Interoperability Data Challenges

Energy trading systems often fail because the same information means different things across systems. This usually occurs as a result of data friction or drifting data definitions.

In practice, this shows up as risk reports that don’t match trading screens or analysts stuck reconciling instead of analyzing.

Data friction shows up when data is hard to access, reconcile, or actually use in day-to-day workflows. Instead of flowing automatically, data gets slowed down or reshaped along the way, increasing the chance that different systems form different views of the same event. Common signals include:

• Manual workarounds. Teams use spreadsheets or file transfers to bridge systems.
• Process latency. Routine reporting, reconciliations, or approvals are delayed because data must be gathered from multiple sources.
• Redundant data entry. The same data is captured in multiple systems because upstream data is inaccessible or not trusted.
• Workflow breaks. Processes stall when data does not automatically flow across systems.

Drifting data definitions arise when the meaning of key data elements differs across teams and systems. Over time, systems may still be connected, but no longer aligned, making communication between systems difficult. Common signals include:

• Conflicting reports. Two reports use the same term with different results.
• Contextual qualifiers. Metrics require verbal explanations.
• Inconsistent aggregation. Totals do not reconcile because underlying assumptions, cutoffs, or hierarchies differ.
• Change without governance. System upgrades, regulatory changes, or new products introduce new interpretations without updating definitions.

Together, data friction and drifting definitions explain why a trade can arrive “on time” and still create confusion. When systems are integrated without shared definitions and consistent data handling, delays and inconsistencies compound… even when the data arrives on time.

Risks From Data Inconsistency

Fragmented systems slow everything down and create inconsistent data, resulting in poor decision-making and increased risk. By the time information is collected from various systems and reconciled, it’s often already outdated — so decisions are made based on a situation that no longer exists.

Decisions based on incomplete, inaccurate, or outdated information are disruptive to traders, risk managers, and schedulers.

In EU power markets, this often shows up around timing mismatches in market data — for example, missing 15-minute price intervals that require fallback logic, republished prices that trigger downstream corrections, or long-dated PPAs indexed to CPI where updated indices arrive at a different cadence. When those updates hit all at once, teams are left explaining sudden P&L moves rather than managing risk proactively.

More broadly, in power trading, when market prices may be dependent on how often the source is able to update, near real-time may be acceptable for some risk views. However, for real-time traders and schedulers, even small delays can mean missing market deadlines – leading to penalties, imbalance exposure, or higher power costs.

Mature APIs in Energy Trading

Because of this disconnect between systems, mature integration environments need to begin with clearly defined, shared semantics. Every product, price, volume, node, interval, or counterparty should have the same business meaning everywhere it appears across trading and risk systems. This includes shared definitions for trades, instruments, locations, time intervals, and attributes, with clear ownership of those definitions.

When a trade is defined consistently based on execution timing across trading and risk environments, it appears predictably in exposure and risk views, eliminating early-morning reconciliation efforts and preventing false risk signals.

Data is clearly defined and consistently applied, with ownership, validation rules, and intentional change management. Critical data has documented definitions, and changes are communicated so updates don’t introduce unintended interpretation differences.

Mature interfaces between systems are predictable, versioned, and designed around business events rather than simple data transport — so changes don’t introduce unexpected shifts in exposure or reporting. They have consistent update cycles, so systems receive data updates when expected and in a form they can reliably interpret. In practice, this means treating shared definitions and timing as part of the integration contract itself — enforced by the system — rather than something teams are expected to reconcile after the fact.

A high-maturity API environment in energy trading is one where scale, speed, and complexity increase without eroding trust in the numbers. It supports timely risk visibility, semantic consistency, and the ability to adapt without introducing new sources of confusion.

Benefits of API Maturity

Mature energy trading APIs provide predictable, governed, semantically consistent system-to-system communication. Across trading and risk environments, that consistency prevents definition drift and reduces the need for manual reconciliation.

API maturity increases the accuracy, timeliness, and reliability of risk data by ensuring that operational events, market data, and trade lifecycle changes are reflected consistently across trading and risk workflows. When data updates arrive in a predictable cadence, risk systems can respond as conditions change, and risk managers can manage intraday exposure with confidence — a shift that fundamentally improves decision-making in energy trading.

In trading organizations, risk accuracy depends on alignment across trade capture, position management, valuation and MTM, and credit exposure. Mature APIs allow these workflows to operate from the same information rather than independently collecting and interpreting data, reducing inconsistencies and false risk signals.

As markets evolve, API maturity enables systems to scale with confidence. Stable, well-defined interfaces support higher volumes, new products, and expanding market coverage without introducing new sources of friction or breaking existing workflows.

How To Determine If Your Integration Architecture Can Scale

The ability to scale as markets and portfolios evolve is an essential component of interoperability. To determine if your integration architecture can scale, you should ask a few key questions:

• Will adding a new system or workflow require modifying existing integrations?
• Can integrations remain consistent as volume and velocity increase?
• Do point-to-point integrations multiply with each new system?
• Does the architecture rely on batch-centric data movement that delays visibility during volatile periods?
• Is hard-coded business logic embedded in interfaces rather than shared services?
• Do vendor- or team-specific queues control changes and enhancements?

If your integration architecture requires too much customization (or disruption) to scale, it will struggle to keep pace with rapidly evolving energy markets.

Why Shared Meaning Matters

As power portfolios scale, consistency becomes more valuable than faster data.

Each new market, product, or data source introduces another place where timing and definitions must stay aligned. Without that alignment, friction compounds quietly — until it shows up as unexplained P&L movement, missed market deadlines, or hours spent reconciling instead of managing risk.

Mature APIs preserve shared meaning as data moves. They enforce consistent definitions and predictable timing so exposure updates the way teams expect it to, even under stress.

As energy trading becomes more interconnected and time-sensitive, shared meaning becomes a structural cornerstone rather than a technical detail. The organizations that build for shared meaning scale with control. Those that don’t scale with friction, or risk not scaling at all.

ETRM (energy trading and risk management) software enables the automation of front-to-back office processes to streamline workflows and proactively monitor risk throughout the trade lifecycle.  

Essential ETRM software features include:

• Deal capture
• Automated position, P&L, and risk reporting
• Risk metrics and valuations
• Value at Risk (VaR)
• FCM reconciliation
• Custom reporting

Given the scope of everything an ETRM can do, paired with the complexity of implementation and maintenance, they can be a significant investment. So, naturally, the next question that someone considering an ETRM purchase would ask is, "How much does an ETRM cost?"

Let’s answer this.

How Much Does ETRM Software Cost in 2026?

Here’s a general range for ETRM costs:

• $150k–$250k/year for most trading companies, plus taxes and implementation fees.
• $100k+/year for smaller, exchange-only companies with simpler needs. However, these businesses may eventually need a more robust, scalable system as they grow.
• $500k/year or more for large companies with enterprise support, physical logistics, and complex workflows.

Contract terms are generally 1-5 years.

Editor’s note: It’s important to keep in mind that the cost of an ETRM software system varies between vendors and can change at any time. Therefore, the best way to get the most accurate cost estimate of an ETRM system is to ask the vendor directly.

What Affects the Price of ETRM Software?

Top factors that drive the pricing quote are:

• Portfolio complexity: The diversity and complexity of traded commodities (e.g., exchange-only vs bilateral, PPAs that are hourly and multi-decade-long) can impact ETRM software requirements
• Number of users: More users often result in higher cost
• Physical logistics needs: A specific set of features are often needed to support logistics
• Expectations around support: Companies may find themselves paying more for premium support packages
• Implementation: The biggest item that changes the cost of the solution – and can ultimately triple in price during the life of an ETRM/CTRM system

Top ETRM Cost Drivers in 2026

According to Molecule’s 2025 ETRM/CTRM Transformation + Modernization Report, ETRM/CTRM adoption climbed from 34% to 85% in just one year, and nearly 94% of companies said they’ve already launched or planned a modernization effort.

With modernization moving from strategy to execution, the wish list for what companies expect in an ETRM is also growing:

• Modernization at scale. Modern systems are now standard across energy and commodities. Companies are investing in scalability, data quality, and stronger foundations that support faster and more precise decision-making.
• Integration and interoperability. Most respondents (71%) use a mix of vendor systems, in-house tools, and spreadsheets. The goal now is connected infrastructure: clean integrations, reliable data exchange, and flexible APIs.
• Legacy replacement. Outdated systems are being retired as organizations move to architectures that can adapt to new markets, products, and regulatory requirements.
• Renewables and new commodities. Renewables and environmental products ranked as the most-traded commodities. Portfolios are expanding, and systems need to handle the complexities of larger data sets, sub-hourly power pricing granularity, and certificate tracking.
• Practical AI adoption. Many organizations are starting small and using AI for reporting, forecasting, and fraud detection, where the benefits are tangible and the results can be trusted.

Why ETRM Implementation Costs Matter in 2026

Implementing an ETRM system is a significant investment — not just in terms of software costs, but also in the time and resources required for a successful rollout. These projects can involve integrating complex portfolios, configuring workflows, and training teams, all of which can add to the overall expense.

For many companies, the biggest cost drivers during implementation are:

• Custom Configurations: Tailoring the system to meet specific business needs, such as specific integrations, complex power purchase agreements (PPAs), or renewable energy portfolios.
• Data Migration and Validation: Ensuring accurate transfer and setup of historical and real-time trading data.
• User Training and Support: Helping teams adapt to new workflows, which can take longer than anticipated without proper planning.

Are There Additional ETRM Costs?

Typically, the price of an ETRM system includes the software itself and an estimate of the implementation cost. Additional ETRM costs may include:

• Market data (i.e., ICE, CME, Nodal Exchange, Platts, Argus, OPIS, LMPs)
• A market data loading/aggregation solution (i.e., a way to get the market data into the ETRM system)
• A business intelligence solution (i.e., custom reporting)

IS MOLECULE'S ETRM SOFTWARE ANY DIFFERENT?

Molecule is more than just another ETRM vendor. We’ve built a modern, easy-to-use platform designed to help you take control of your data for faster, smarter decision-making.

Here’s what sets Molecule apart:

1. Unlimited Integrations
   Molecule connects with your existing tech stack, so you can take control of your data to make better and faster decisions.
2. Scalability and Flexibility
   Our cloud-native architecture allows you to scale with ease as your portfolio grows or your business needs evolve.
3. Intuitive Design
   A sleek, easy-to-use interface reduces the learning curve so you can get the most from your system from Day One.
4. SaaS Efficiency
   As a cloud-native, multi-tenant ETRM solution, Molecule doesn’t require custom builds for every new customer, saving you implementation time (and associated costs).
5. Shorter Contracts
   Our contracts are typically 1–2 years. If you renew your contract with us, it's a much smoother process with your data already in our system.

We are transparent about our implementation timelines. Once you become a Molecule customer, we can determine an implementation project plan that includes the following:

• Configuring our app and integrations to your needs
• Loading your trades
• Validating your data
• Helping to build your reports

We also have built-in integrations for FCMs, major exchanges, and market data if the vendor permits. Moreover, we include LMPs and block pricing for North American ISOs. We even have built-in tools that automatically load data.

The Value of Cloud-Based, Multi-Tenant ETRM Software

If you’re going to invest in an ETRM software system to manage your trade risk operations, it makes sense that you would want a system that works best for you in both the short- and long-term.

Different types of ETRM software systems include:

• On-premise (“on-prem”): All of your data is stored on a physical, on-site server, which is expensive and requires ongoing maintenance. Many legacy systems are on-prem.
• Cloud-based: If the ETRM is cloud-based, that means your data is not stored in a physical location, but in a data center. A cloud-based ETRM can either be single-tenant or multi-tenant.
• Single-tenant: In a cloud-based ETRM, hardware may be on shared infrastructure, but the software only serves one company.
• Multi-tenant: In a cloud-based ETRM, both the hardware and software are on shared infrastructure; however, each company operates independently.
• Hybrid: Combined features of on-prem and cloud-based ETRM solutions.

Many forward-facing trade risk companies choose multi-tenant ETRMs for several benefits:

• Lower implementation fees
• Reduced ongoing maintenance costs
• Instant access to the latest updates
• Get up and running sooner for the fastest time to value

ETRM Costs in 2026

ETRM pricing continues to vary across the market and from vendor to vendor, but the factors shaping total cost are also shifting. As portfolios expand, ETRMs often need to connect to more systems, such as exchanges, ISOs/TSOs, registries, analytics, and other platforms being used across the trading organization. The need to handle greater complexity — not just scale — is influencing what companies consider essential in an ETRM.

This shift in priorities is influencing how companies assess long-term value when comparing ETRM options in 2026. Organizations investing in modern ETRMs are positioning themselves to remain competitive, scale operations, and handle growing and more complex portfolios.

Whichever modern ETRM you choose, ensure it supports both your immediate trading needs and your long-term business goals.

FREQUENTLY ASKED QUESTIONS

1. What's the difference between an ETRM and a CTRM?
   ETRMs focus on energy commodities, while CTRMs focus on commodities such as metals, agriculture, and cryptocurrency. Although both manage trade and risk, ETRMs are built to handle the complex demands of the energy markets.
2. What is ETRM in trading?
   ETRM (energy trading and risk management) software is designed to help mitigate risks associated with energy trading, with real-time monitoring and reporting of exposures to market price volatility.
3. Who uses an ETRM?
   ETRMs are utilized by traders, risk managers, and back-office personnel at energy producers and consumers, hedge funds, utilities, and other organizations. They are an essential tool for successful energy trading and risk management, enabling the mitigation of risk, compliance, and optimization of portfolio performance.
4. What types of commodities do ETRMs handle?
   ETRMs specialize in energy commodities, such as electricity, natural gas, jet fuel, and crude oil. Renewables like solar, wind, and hydropower are also considered energy commodities, but not all ETRMs can handle renewables.
5. Do ETRMs support renewable power trading?
   Modern ETRMs can support renewable energy commodities such as solar, wind, and hydropower. Since these portfolios tend to be complex with large datasets, it’s important to choose an ETRM that can handle the complexities of renewable energy trading such as renewable certificates. This includes both generation portfolios and renewable certificates.

Editor’s note: This blog was originally published in 2021. It has been updated and republished for 2026.

• PPA complexity has increased as renewable energy production expands and electricity grids struggle to handle the influx of intermittent energy
• Dynamic PPAs have become a powerful tool for managing risk in renewable power trading
• Managing renewable PPAs requires modern power trading systems

Renewable PPAs have always balanced risk and reward, but today, the variables behind those contracts move faster and with far more volatility than before. As renewables scale and interact more directly with real-time markets, their intermittency, congestion impacts, and credit implications surface immediately in trading and risk views. New hybrid renewable energy systems — for example, co-located solar, wind, and battery storage assets — further increase complexity.

As these physical and market dynamics intensified, the contractual structures around them had to evolve as well.

Renewable PPAs have evolved to keep pace, moving from static 10-year contracts to shorter-term contracts or contracts with floating/indexed pricing or options to renegotiate rates during the contract.

However, every curtailment notice, renegotiated contract, and credit call tells the same story: renewable PPAs changed faster than the systems managing them. Many static trading systems, such as spreadsheets and older platforms without real-time data feeds, can’t keep pace with these dynamic instruments. This mismatch exposes hidden risks in cash flow, credit, and confidence.

These shifts have outpaced the tools and processes many trading and risk teams still rely on, leaving portfolios exposed in ways that were easy to overlook before.

Table of Contents

1. How Renewable PPAs Became More Dynamic
2. Why PPA Complexity Keeps Rising
3. How Curtailment and Congestion Reshape Risk
4. How Hybrid PPAs Reshape Portfolio Strategy
5. Where Legacy Trading Systems Break Down
6. Visibility, Not Complexity, Drives Control
7. The Future of PPAs in Modern Power Trading
8. Frequently Asked Questions

How Renewable PPAs Became More Dynamic

Historically, PPAs were straightforward, long-term contracts where buyers locked in a fixed price for renewable electricity for 10-20 years. These long-term contracts benefit sellers by providing a guaranteed revenue stream, making financing projects easier and reducing risk.

In some cases, a corporation is the sole buyer of energy generated, such as Siemens Energy’s agreement to purchase up to 40 GWh of solar power per year from German electric utility EnBW Energie Baden-Wuerttemberg AG.

In others, a PPA provides the financial security required to ensure the project is built at all, such as Amazon’s agreement to purchase electricity from a solar project that will not begin operations until 2027.

Static contracts are one-directional instruments with predictable cash flows, minimal flexibility, and little interaction with market dynamics. Risk (price, volume, market) is mostly assumed by the buyer in exchange for long-term price stability.

Today’s energy landscape is more volatile due to intermittent renewables, electricity storage challenges, and fluctuating demand. Shorter-term wholesale prices can swing dramatically, often spiking with scarcity or grid congestion. A week with little wind can top market news, such as when a lull in wind had Germany and France bracing for price swings as high as €280 and as low as €57 per megawatt-hour in two days.

That level of volatility means that locking in a single fixed price for 10–20 years carries serious risk to buyers. Renewable PPAs had to become more dynamic to mitigate that risk.

Modern renewable PPAs now interact with real-time markets, credit systems, and sustainability frameworks. Many PPAs use floating or indexed prices, exposing both buyer and seller to real-time market movements. Contracts are shorter and often renegotiable, allowing portfolio adjustments. They distribute risk through caps, floors, or collars, so risk is no longer solely carried by the buyer.

At the same time, long-term PPAs can be used as hedging instruments and carbon accounting tools.

• For offtakers, a fixed- or indexed-price PPA can serve as a natural hedge against wholesale market volatility.
• For generators, the contracted revenue floor reduces exposure to merchant price swings and supports project financing.
• Because a PPA attributes renewable generation to an offtaker, the PPA procures verified zero-carbon attributes, reduced Scope 2 emissions, and demonstrated progress toward RE100 or internal climate commitments.

As PPAs have evolved, the risks surrounding them have evolved even faster, especially as real-time markets intensified price, volume, and credit exposure.

Why PPA Complexity Keeps Rising

Dynamic PPAs introduce a new layer of PPA complexity and price volatility, increasing market, credit, and operational risks.

• Floating or partially indexed contracts expose portfolios to wholesale price swings, including negative prices.
• Grid congestion and curtailment events reduce delivered volumes, cutting into expected revenue.
• Volatile settlements affect working capital and liquidity, undermining credit confidence across portfolios. Weaker credit metrics make it more difficult, and more expensive, to borrow.

These risks are especially aggravated with traditional, siloed trading systems that can’t track exposures in real time, leading to blind spots and delayed responses to performance or pricing issues. Additionally, as portfolios expand across regions and structures, inconsistent terms and fragmented data make it difficult to assess true exposure or hedge effectively.

As a result, buyers must continuously monitor and optimize around their PPAs, balancing cost certainty, carbon impact, and flexibility. Sellers must offer PPAs that can attract new classes of investors or counterparties seeking exposure to renewable assets, turning PPAs into financial products that are traded and structured with other hedging instruments to manage risk distribution across the energy ecosystem. This is a large shift from the 20-year, “set and forget” contracts of old.

How Curtailment and Congestion Reshape Risk

Curtailment and congestion both result in the same outcome: less energy being delivered, lower revenue, and increased credit risk. Both are the result of an overabundance of renewable energy. Sometimes, curtailment is mandated by the grid operator; in others, generators voluntarily go offline when prices turn negative because it’s cheaper to stop producing than to sell.

Curtailing electricity reduces delivered volumes and results in less energy sold under the PPA, which decreases profits. In some markets contracts include compensation mechanisms, but these mechanisms only cover a portion of the loss. Because fixed O&M and financing costs stay constant while production drops, margins are reduced, impacting liquidity. Persistent curtailment can lower project valuations.

Congestion also creates price separation between the project’s node and the market hub, increasing basis risk. The PPA may settle at one price while the project realizes another, resulting in reduced realized prices versus contracted benchmarks and increased hedging costs if congestion is managed through FTRs or other hedging instruments. Mark-to-market losses on congestion-linked derivatives or PPAs can trigger margin calls or collateral postings, creating sudden liquidity pressure. Separately, disputed or delayed settlements may arise from nodal pricing differences, weakening accounts-receivable stability and straining operational liquidity.

When counterparties face liquidity pressure, credit exposure cascades across the portfolio. ECLs on counterparties increase, hitting earnings directly. Lenders or investors demand higher spreads or tighter covenants as perceived risk rises. Contracts may be renegotiated under stress, with unfavorable terms reducing long-term revenue. Lower revenue inflows and higher credit provisions impair DSCR and other financial covenants.

How Hybrid PPAs Reshape Portfolio Strategy

Hybrid systems that combine renewable energy production and storage are increasingly viewed as key to unlocking efficiency and cost savings. When renewable energy is stored where it is generated, it does not have to move through the grid to be stored, reducing both energy losses and overload on the electricity infrastructure.

Therefore, hybridization can be an effective strategy to create new generation capacity without expanding local distribution and transmission grids. This is especially critical in Asia-Pacific, where grid flexibility is a major bottleneck to renewable energy. For traders and risk teams, hybrid assets also reshape how PPAs are structured and settled, adding new layers of operational and financial complexity to portfolio strategy.

Hybridization generates more data and more complexity, requiring accurate, timely analysis to navigate.

Where Legacy Trading Systems Break Down

Many legacy renewable trading systems were designed for predictable, one-directional contracts, not today’s dynamic, market-linked PPAs. They assume scheduled energy deliveries with fixed pricing terms, not modern PPAs with hourly settlements, price indexation, and nodal variability. These assumptions increase risk and costs:

• Data models built for monthly billing or static forecasts can’t handle high-frequency updates, resulting in blind spots in realized versus expected performance, imbalance costs, and hedge effectiveness.
• Financial reporting is often backward-looking and disconnected from live market or operational data, but today’s risks emerge hourly — when curtailment hits, when congestion changes nodal spreads, when a counterparty’s margin call is triggered.
• CFOs and risk teams can’t see how operational volatility translates to P&L swings or liquidity exposure until it’s too late.
• Contract management, asset operations, and finance systems rarely talk to each other, and when data is fragmented, risk compounds.
• Curtailment, congestion, and credit events are cross-functional, originating in one system and surfacing in another. In legacy systems, teams react to indicators after events, not the actual events.

While many legacy PPA modules were coded for fixed prices and predictable volumes, modern PPAs include caps, floors, collars, volume tolerance bands, and market-based settlements. Legacy logic can’t calculate or simulate these terms, so they miscalculate exposures, underreport mark-to-market changes, and produce false confidence in portfolio performance.

Organizations that still rely on spreadsheets and human reconciliation for PPA settlements and exposure tracking struggle as portfolios expand across markets. The number of data points, settlement types, and counterparties grows exponentially, and manual reconciliation creates delays, inconsistencies, and operational risk, especially during stress events or credit calls.

Today’s PPA management systems need to be real-time, data-native, and cross-functional, uniting operational, market, and financial intelligence in one dynamic risk view.

Visibility, Not Complexity, Drives Control

Losses often occur when an operational event isn’t reflected in financial data until it’s too late. System interoperability closes those gaps. By connecting the physical and financial sides of renewable portfolios, users can move from reactive management to proactive strategy.

With a modern renewable power trading system, APIs and data standards link contract management, ETRM, forecasting, and accounting tools, creating a single source of truth and giving users the power to control what they see, when they see it, and how they see it.

• When markets move hourly and settlements shift daily, risk is revealed in real time, providing a foundation of control.
• Integrated data visibility combines generation, pricing, curtailment, and settlement data into a single view, unveiling exposures before they crystallize.
• Granular transparency lets teams pinpoint which assets, contracts, or counterparties are driving variance in cash flow or credit.
• Scenario modeling and forecasting let portfolio managers simulate outcomes, such as price shocks and curtailment events, and take pre-emptive action.
• Continuous data flow between grid telemetry, pricing feeds, and finance systems keeps exposures current, eliminating reconciliation delays.
• Cross-functional dashboards ensure commercial, finance, and risk teams work from the same metrics and timelines, building a unified risk language.

With shared visibility and connected systems, confidence grows at every level. Transparent reporting reduces perceived uncertainty, supporting valuation stability and financing capacity.

CFOs and credit officers have clear, auditable links between operational events and financial outcomes that improve covenant compliance and investor trust. Developers and asset managers can use performance data to strengthen their position in PPA negotiations and credit discussions.

Organizations that embrace data-driven transparency can better navigate volatility, treating every curtailment, renegotiation, or credit event as a signal to adjust.

The Future of PPAs in Modern Power Trading

Renewable energy PPAs are one of the most versatile instruments in modern power trading. They combine long-term financial hedging, real-time physical risk, and carbon economics in a single instrument and can be used to hedge load, support new project development, manage emissions reporting, and provide directional trading exposure.

Renewable PPAs are that powerful because of their complexity, so managing them correctly is critical. While traditional PPAs could be signed and ignored for 10-20 years, today’s dynamic PPAs require continuous analysis. Renewable energy prices can change with a shift in the wind, so buyers must monitor and optimize them continuously to balance cost certainty, carbon impact, and flexibility.

Renewable PPAs changed faster than the systems managing them, exposing traders to risks that can be avoided through modernization. And, that modernization needs to happen soon, because renewable energy is evolving, and expanding, and the risks will multiply if systems fall further and further behind.

Frequently Asked Questions

• Renewables and increasing demand for power are testing power market pricing models
• Effectively managing grid congestion with inconsistent power sources (e.g., renewables) requires granular pricing
• Nodal pricing volatility is less disruptive than inaccurate supply-demand signals in zonal markets

Every few months, traders watch day-ahead power prices separate across zones or nodes, even when total generation and demand barely change, revealing hidden congestion on the grid. These differences reflect the design of the market itself, dictating who sees congestion early, who pays for it later, and who never sees it coming at all.

How prices form, how risk travels, and who bears the cost when the grid gets stressed all trace back to market design. For years, that framework remained stable enough to trust and simple enough to ignore. But as renewables grow, transmission lags, and demand patterns shift, those hidden rules have become a decisive variable in trading outcomes.

Across the world, zonal, nodal, and hybrid systems are rewriting how power markets work. Europe’s single-price zones, the U.S.’s node-level models, and Asia’s emerging hybrids all balance the same tension: simplicity versus precision, visibility versus volatility. How each market draws that line shapes everything from congestion risk to cashflow timing. In an era defined by renewables, decentralization, and data, market design has quietly become the architecture of opportunity and exposure. That balance between simplicity and precision now defines how resilient and profitable each market can be.

In this article, we trace how those invisible rules determine who captures value, who absorbs risk, and how design itself has become strategy in modern power trading.

Table of Contents

1. Implications of Different Pricing Models
2. Innovation Is Stress-Testing Power Distribution
3. The Hidden Costs of Zonal Pricing, Masking Supply and Demand Signals
4. The Future Is Nodal (or Hybrid With Nodal Elements)
5. Global Power Trading in Nodal Markets
6. Modern Markets Need More Granular Pricing

Implications of Different Pricing Models

The three market structures —nodal, zonal, and hybrid — influence global power trading in a few critical ways.

Pricing Accuracy

Nodal markets segment the grid into thousands of individual pricing points, producing more granular (and therefore more accurate) price signals than aggregated zonal markets. For example, regions with abundant wind power in Texas experience lower (even negative) prices compared to other areas of Texas because the regional pricing reflects that extra power. Nodal prices also include transmission constraints, with components for marginal generation costs, marginal losses, and marginal congestion.

Zonal markets are much larger (for example, a single day-ahead price covers all of Germany or all of France, whereas ERCOT in Texas has more than 17,000 pricing nodes, each with its own local price), and the price for each zone is based on the aggregated supply and demand across the entire zone without regard for local variation and constraints.

Hybrid pricing lands between the two. It often has zonal pricing with some nodal pricing elements within the zones. For example, Italy uses zonal pricing for day-ahead wholesale electricity trading, but employs a more granular pricing for intraday, flexibility and balancing markets within those zones. In addition, Italy’s prices are influenced by its market-coupled neighbors; France, Austria, Slovenia and Greece. For traders, that detail determines whether congestion appears as real-time volatility or as surprise uplift after settlement.

Volatility and Risk

Nodal markets distribute risk according to localized grid conditions, so they experience high price volatility when individual nodes experience transmission constraints. This structure tends to create significant, localized price risk. Nodal market participants also face a higher degree of basis risk. Traders rely on FTRs and CRRs to manage congestion risk and hedge basis exposure, but they also use them opportunistically, capturing spreads between nodes or zone bundles when congestion patterns persist. By using an FTR to offset the difference in the day-ahead congestion price between the source and sink, traders can effectively guarantee a fixed congestion price differential and limit the financial hit from unexpected congestion. Even so, these instruments can’t remove locational volatility entirely; they just make it tradable.

Because zonal markets spread price risk evenly across a geographical area, prices are less volatile. There is no zonal basis risk for intra-zonal transactions. Basis risk becomes a factor for trades between zones, and long-term transmission rights (LTTRs) and their variations are used to hedge against this risk.

Hybrid designs may include nodal pricing within zones, so risk distribution is a blend of both models and volatility is distributed in a more complex way. For example, some hybrid designs may experience high spot market volatility but offset it with forward contracts.

Supply Signals

Nodal pricing sends strong, location-specific signals that attract new generation where it’s needed and prompt curtailment where grids are tight.

Because zonal markets do not reflect the true cost of delivering electricity to specific locations, they do not accurately reflect local market conditions. This can result in ineffective responses to power demand and encourage new generation in suboptimal locations.

Hybrid markets often pair local price signals with investment incentives — like the U.K.’s tolling agreements for battery storage — to steer capacity toward congested areas.

Complexity

The granular nature of nodal pricing makes it complex to implement and understand. Energy prices can shift minute to minute, so systems need to be able to calculate and adjust in real time.

Zonal pricing is simpler. Since the price in each zone is aggregated across the entire zone, it is easier to implement and understand.

Hybrid markets with nodal elements add some of the complexity of nodal pricing. The upside: better data makes that complexity manageable.

Innovation Is Stress-Testing Power Distribution

Nodal and hybrid markets are gaining interest in the face of unprecedented localized demand fueled by new heavy power users (e.g., data centers) that require power 24/7 to support continuous computing systems. Electricity consumption from data centers has been growing at 12% per year over the last five years, and this trend is poised to continue.

At the same time, technological advancements and a commitment to clean energy targets have increased production of renewable energy. While the additional power generated by solar and wind is needed, power grids designed for centralized fossil fuel plants struggle to integrate renewable power. The fundamental design of these older grids is based on a predictable, one-way flow of electricity from a few large generation facilities to consumers.

Renewable sources like solar and wind are intermittent and unpredictable, generating power only when the sun is shining or the wind is blowing. This makes it difficult for grid operators to balance supply and demand in real-time, potentially leading to instability. Battery technology remains insufficient to store energy created, forcing power companies to rely on backup power sources during cloudy weather, nighttime, or calm weather. Together, these shifts are exposing how legacy market designs hide stress, rather than price it.

The Hidden Costs of Zonal Pricing, Masking Supply and Demand Signals

One of zonal pricing’s biggest weaknesses is its inability to reflect real grid conditions. Most zonal market models assume power flows freely within a zone. When power demand increases, the software searches for the cheapest power to provide. If there is unseen grid congestion, grid operators must manually redispatch and pay generators in congested areas to reduce output and pay other generators to increase output. If this redispatch is not enough to maintain grid stability, operators may incur additional costs for emergency actions, such as ordering offline generation units to come online.

Zonal pricing also masks supply signals. Because renewable energy varies with weather conditions, a windy day can create an abundance of power that creates grid congestion in localized areas. In many markets, redispatch volumes have been climbing as renewables outpace grid capacity.

Because zonal pricing hides inefficiencies in the zone, it may disincentivize innovation and the deployment of flexible resources like energy storage that could relieve local congestion. Zonal pricing often encourages power development in low-cost areas, far removed from actual demand, without accounting for the grid costs of getting that power to consumers. That growing gap between physical reality and market signals is pushing more regions to test nodal approaches.

The Future Is Nodal (or Hybrid With Nodal Elements)

Momentum for nodal and hybrid designs is building worldwide. Multiple studies across Europe and North America have estimated the benefits of transitioning to nodal pricing to be between 1 and 4% of operational costs, which would translate into savings of several billion Euro per year in the EU. U.S. markets that transitioned from zonal to nodal markets recouped the implementation costs within one year of operation; proof that efficiency and transparency can pay for themselves.

• Nodal markets provide a clear price incentive for generators in congested areas to reduce their output, automatically determining the most economically efficient way to dispatch generation.
• Congestion costs are clear, reducing the need for expensive, administrative redispatch actions.
• Nodal pricing signals encourage investment in projects that alleviate congestion, providing a strong signal to developers to build new generation closer to demand centers.
• It can lead to lower carbon emissions and more efficient use of resources by reducing the need to curtail cheap, renewable power.

Still, these transitions demand strong governance and high-quality data.

Global Power Trading in Nodal Markets

Balancing surging, localized demand with variable renewable supply increasingly depends on advanced forecasting, risk management, and analytics. That means managing massive volumes of real-time data from market feeds and smart meters.

More sophisticated risk assessment models are required to manage the increased volatility and market complexity inherent in finer-grained and hybrid pricing models. Credit assessment models must factor in the volatility of nodal and short-term market prices. Real-time data should be used to monitor credit exposure against limits for all trading partners to prevent a single counterparty default from causing significant financial disruption.

Nodal and hybrid markets have higher basis risk that must be managed using instruments like FTRs or basis swaps. Sophisticated hedging strategies, including financial derivatives, block-and-index purchasing, and load-following blocks can mitigate exposure to market volatility. CRRs can be used to hedge against financial risk caused by transmission congestion.

Modern Markets Need More Granular Pricing

Investment in renewable energy is not going to stop. New uses for AI will create more demand for computing centers, requiring still more power. We have no idea what the next technological breakthrough will be, but we do know it will likely require power to run.

While the detailed nature of nodal pricing makes nodal markets more complicated and pricing more volatile, that volatility provides key market insights to energy producers, traders, and consumers. Visibility into demand and supply at a granular level is the only way to ensure power keeps pace with innovation, and innovation in power is focusing on the right areas.

Without that visibility, power markets risk higher costs, grid congestion and inefficiency, and investment in locations that do not support actual demand. It just won’t work long term.

Thanks to advances in computing power and analytical tools, managing nodal pricing keeps getting easier — and the excuses to stick to zonal pricing fall away. Nodal pricing is proving more effective in today’s modern power grid, enabling more seamless integration of renewable energy and ensuring new power sources will be developed in optimal locations to match increasing demand for power.

Frequently Asked Questions

The biggest takeaways from Molecule’s 2025 ETRM/CTRM Transformation + Modernization Report

Summary: The State of Modernization in 2025

2025 is the year energy and commodities trading companies stop talking about modernization — and start building it. Last year, the majority of companies were still mapping their plans. This year, modernization has moved from strategy to execution.

Priorities have changed from last year, too. Speed still matters, but control, scalability, and trust in data are now the real metrics of success. As portfolios grow more complex and renewables claim a bigger share of the mix, companies need systems that can keep up — without forcing workarounds or custom patches.

This year’s report, built from over 400 responses across 10+ industries, shows how far the market has come… and where it’s still stuck. The message is clear: firms don’t just want faster systems; they want systems that flex with their business, provide clear answers when the stakes are high, and remove the guesswork from risk and compliance.

This article breaks down the biggest takeaways from this year’s ETRM/CTRM Transformation + Modernization Report.

Table of Contents

1. Top Takeaways
2. Why Is 2025 the Tipping Point for ETRM Modernization?
3. What Is Driving Modernization in 2025?
4. Control, Scalability, and Confidence Are the New Winning Metrics
5. Where Are Current ETRM Systems Falling Short?
6. What Do Energy and Commodity Teams Actually Want?
7. How Are Renewables Reshaping ETRM Priorities?
8. What Role Will AI Play in Trading Operations?
9. Why Modernization Will Decide Future Market Leaders

Top Takeaways

What’s shaping the energy and commodities trading market in 2025?

• 70% of companies have modernization projects already in motion (up from 24% in 2024).
• 94% have launched or planned modernization initiatives.
• ETRM/CTRM adoption has skyrocketed from 34% to 85% in one year.
• Scalability is the #1 driver for modernization (led by 43% of traders, 29% of producers, 25% of utilities).
• 64% say their current ETRM systems still don’t support all their processes or traded commodities.
• Operational visibility (31%) now beats agility (23%) as the top long-term risk priority.
• 91% expect AI to reshape trading operations within five years.

Why Is 2025 the Tipping Point for ETRM Modernization?

Modernization has shifted from a “future goal” to a current operational priority. In 2024, 66% of companies were still in the planning stage, with only 24% having a modernization initiative actively underway. In 2025, companies are fully committing to modernizing their trading operations.

• 70% already have projects underway, compared to just 24% last year.
• ETRM adoption jumped from 34% in 2024 to 85% in 2025.94% of companies have launched or planned modernization initiatives — nearly universal adoption.

The data underscores that modernization is no longer optional for companies that want to remain competitive, efficient, and compliant.

Companies that invest now are positioning themselves for future growth, operational efficiency, and compliance readiness — while those who wait risk falling behind.

What Is Driving Modernization in 2025?

As portfolios grow more complex and market volatility increases, companies are doubling down on infrastructure that can scale and adapt.

• Scalability is the #1 modernization driver across most company types, particularly for Traders and Utilities where operational complexity is highest.
• 64% of respondents report that their systems fail to fully support critical business processes or the range of commodities they trade.
• Renewables have surged to become the most-traded commodity (42%), overtaking oil and gas.
• 91% expect AI to play a major role in reshaping trading operations within the next five years.

These numbers point to bigger trends shaping the industry:

• The rise of renewables and new products demanding more adaptable systems
• The need for integrated, automated tools that remove manual bottlenecks
• The race to stay ahead of evolving market dynamics

Together, they paint a picture of a sector undergoing significant digital transformation.

Control, Scalability, and Confidence Are the New Winning Metrics

Speed was a major theme of last year’s report, but it’s now the baseline expectation. What companies really want in 2025 are systems that provide confidence, control, and scalability — platforms that can handle both current needs and future growth.

Scalability leads the way:

• 43% of Traders, 29% of Producers, and 25% of Utilities identified scalability as their top priority.
• Business efficiency (16%) and new business growth (12%) are emerging as the secondary reasons behind modernization.

Control means better oversight, less manual intervention, and more reliable data. Scalability ensures that as portfolios diversify, your systems won’t break or slow you down. Confidence means trusting that your system will deliver accurate, timely insights that support critical decision-making.

Where Are Current ETRM Systems Falling Short?

Even with new investments, most companies are still frustrated with their current system. Legacy platforms struggle to handle the speed, data, and product diversity that today’s trading environments demand.

• 64% of respondents say their system doesn’t support all necessary processes or trades.
• 31% say their system doesn’t handle all commodities — an increase from 21% in 2024.
• Fewer than 4 in 10 respondents say their system handles diverse trade types effectively.

Functionality Gaps: Importance vs Effectiveness

Gaps in trade-type support, scheduling, and reconciliation slow teams down and create real operational risk. And as portfolios expand into renewables and more complex instruments, those gaps in effectiveness are expected to expand.

This growing mismatch between what teams need and what systems deliver is why modernization has shifted from a “nice-to-have” to a must-have. The systems many firms relied on simply weren’t built for today’s complexity — or what’s coming next.

What Do Energy and Commodity Teams Actually Want?

When asked about missing functionality, respondents were vocal about the need for smarter, connected, and scalable systems. Modern ETRM solutions should remove bottlenecks, automate repetitive tasks, and provide a single source of truth for all trading activities.

• Real-time insights and dashboards for clear risk visibility.
• Automated workflows that minimize errors and manual work.
• Cloud-native infrastructure for easy scalability and faster performance.
• Straightforward integrations (especially APIs) that unify data across platforms.
• Advanced analytics for better forecasting, real-time analysis, and smarter decision support.

How Are Renewables Reshaping ETRM Priorities?

The growth of renewables trading means a growing shift in trading strategies, portfolio structures, and system requirements.

• 42% of respondents now trade environmental products — surpassing oil and gas for the first time in our survey.
• Biofuels (33%) and environmental products (30%) rank among the fastest-growing priorities, alongside renewable certificates and carbon markets.
• Legacy ETRMs are falling behind, struggling to manage the data demands, variable pricing models, and compliance reporting that come with these emerging markets.

Regulation is part of the shift, but the real driver is a strategic pivot toward low-carbon portfolios. Companies are leaning in to stay competitive, but that move creates new operational pressure: more complex trades, more data flowing between systems, and tighter reporting timelines.

Modern ETRMs have to keep up with today’s demands. That means supporting diverse products, near-real-time reporting, and carbon accountability — all while integrating with the rest of their trading tech stack.

What Role Will AI Play in Trading Operations?

Artificial Intelligence is becoming a real, measurable force in ETRM operations, with trading organizations seeing AI as an operational accelerator.

• 91% believe AI will significantly impact their trading operations within 5 years.

Top use cases include:

• Automated reporting (18.7%)
• Algorithmic trading (18.2%)
• Predictive forecasting (16.8%)
• Fraud detection (15.1%)

Why Modernization Will Decide Future Market Leaders

In 2025, over 70% of companies now have active modernization initiatives underway, and ETRM/CTRM adoption has jumped to 85%. Companies aren’t just talking about upgrading their systems anymore — they’re doing it.

The drivers for modernization are shifting. In 2024, speed was a headline priority; this year, it’s about control, scalability, and clarity. This points to a maturing market that realizes that the tools they use need to do more than move fast; they need to help drive their business goals.

Today’s trading teams need systems that can handle multi-commodity portfolios, support tighter oversight, and deliver reliable, timely data when decisions can’t wait. As portfolios diversify and compliance demands rise, the gap between firms modernizing strategically and those standing still is widening fast.

“Good enough" isn’t good enough anymore. Companies modernizing now are better positioned to make decisions they can trust, manage risk strategically, and maintain their edge as the market continues to evolve.

1. Manual workarounds create risk. Without power-specific tools, teams lose time stitching together data — increasing the chance of delays, blind spots, and bad decisions.
2. Up-to-date exposures are critical. Power markets shift fast. ETRMs built for power reflect exposures as they change, helping traders respond with speed and confidence.
3. Power portfolios need purpose-built tools. Traditional systems weren’t designed for power. A modern ETRM offers the scale, flexibility, and precision to keep up.

Power markets are hard enough to keep up with — and they’re only getting more complex.

More congestion. More regulations. More structures  to capture, trades to reconcile, and risks to manage. Spreadsheets can’t scale as portfolios become more complex, and legacy systems aren’t built for today’s challenges.

If you’re managing a growing power portfolio, you need a system that keeps up — one that tracks exposures as they shift, reflects risk in real time, and gives you the data you need to act with confidence.

Table of Contents

1. Why Is Power Trading So Complex?
2. What Makes an ETRM Purpose-built for Power?
3. Tracking the Lifecycle of a Power Trade
4. Key Features of an ETRM Built for Power Trading
5. Managing PPAs, Renewable Certificates, and Power Market Risk in Your ETRM
6. What to Look for in a Modern ETRM for Power Trading
7. Why Power Trading Needs a Purpose-Built ETRM

Why Is Power Trading So Complex?

Power trading comes with unique challenges. Unlike many other commodities, electricity must be balanced in real time: supply and demand must match moment to moment, across regionally fragmented markets and shifting regulations.

Markets are fast-moving, and traders don’t just monitor price movements. They track generation, outages, congestion, transmission paths, and changing forecasts — all while adapting to evolving regulatory and market participation rules.

Manual data manipulation takes too long. Every delay introduces risk. And as portfolios grow to include renewable assets and complex PPAs, the operational burden only increases.

To effectively navigate today’s power markets, you need near real-time data with accuracy you can rely on — not just for deal capture, but for forecasting, hedging, and responding to market shifts as soon as they happen.

What Makes an ETRM Purpose-built for Power?

Not all ETRMs are built to handle the complexities of power trading. In fact, many energy trading and risk management systems were originally designed for simpler commodities: where trades follow a linear lifecycle, market data updates slowly, and delivery is less nuanced. That’s not the case with power.

Well-designed ETRM systems are designed to manage the entire power trade lifecycle, offering features like near real-time valuations, trade limit monitoring, certificate matching, and compliance reporting — all of which need to operate at the speed and specificity of the power market.

What Your ETRM Needs to Handle for Power Markets

ETRMs specifically developed for power markets support common power-specific trades and products across forward, real-time, and day-ahead markets, including:

• Financial and physical power trades, with attributes like delivery shape, block hours, and region-specific rules
• Congestion hedges and transmission rights, used to manage delivery path costs and grid congestion
• Day-ahead market positions, cleared via system operators or exchanges
• Ancillary services, used to participate in reserve, regulation, or other grid-support functions
• Renewable credit instruments, such as certificates or guarantees of origin, tied to compliance or voluntary programs
• Power Purchase Agreements (PPAs), used to structure long-term offtake agreements with delivery and settlement complexity

Because of the complexity of these trades and market requirements, power-specific functionality within an ETRM is required to manage them. Without it, you will need to manually collect and evaluate constantly changing information. Minutes (and even hours) can be lost between data acquisition and data response, leaving you vulnerable to outdated data and exposed to unnecessary risk.

Tracking the Lifecycle of a Power Trade

Trade capture is just the start. Between forecasting, delivery, and reconciliation, every step in the trade lifecycle introduces risk — and complexity.

Modern ETRMs purpose-built for power markets go beyond deal capture. They track and automate the entire post-trade lifecycle across physical and financial trades.

The best ETRM for power markets will:

• Seamlessly and automatically capture trades with power-specific attributes like delivery hours and block type
• Incorporate proprietary/fundamental load, generation, and price forecasts into system
• Integrate with system operators to ingest market results, including schedules, dispatch instructions, congestion and balancing data, ancillary service awards, and settlement details
• Validate and handle settlement logic for both vanilla and structured instruments
• Manage the complete lifecycle of your renewables certificates — including trading, forecasting, minting, and traceback
• Support PPAs throughout the contract lifecycle, from valuations to reporting

When your ETRM automates these steps in near real time — and integrates with exchanges, ISOs, TSOs, registries, and market data sources — you get a single, accurate view of your entire portfolio. That means faster decisions, backed by data you can trust.

Key Features of an ETRM Built for Power Trading

Power pricing changes fast… and changes often.

Between day-ahead awards, real-time market fluctuations, and grid congestion costs, even small delays or gaps in your pricing data can mean the difference between profitable decisions and costly ones.

When every 15-minute interval matters, you can’t risk outdated data, broken workflows, or missing settlement info.

Here are the key features an ETRM built for power trading should have:

• Automatically pull in market data and awards from connected ISOs and TSOs
• Report on forward and intra-month positions and P&L
• Automatically reconcile with futures clearing merchants/brokers
• Support reconciliation and tracking for generation and storage trades
• Generate confirmations and invoices
• Provide all trade lifecycle data on-screen and via APIs

In short: the best ETRM for power trading delivers fast and accurate pricing, forward visibility, and a clear understanding of how market changes affect your bottom line.

Managing PPAs, Renewable Certificates, and Power Market Risk in Your ETRM

Accurate volumetric  data tracking is table stakes in power — but actually executing it across deliveries, contracts, and certificates is where many systems fall short. A purpose-built ETRM should track and compare actual volumes against contracts and reconcile renewable certificates with physical deliveries — keeping your numbers both auditable and reliable.

What To Look for in a Modern ETRM for Power Trading

The most important feature of a power-ready ETRM is that it is purpose-built for power portfolios, PPAs, and renewables.

It should have:

• Flexibility and scalability necessary to handle growing complexity and larger volumes of data
• Prebuilt integrations for power trading with ISOs, TSOs, exchanges, brokers, and market data sources
• Support for diverse energy commodities (power, carbon, gas, RECs)
• Built-in features for physical commodity management, including product mapping, market and exchange data integrations, and ICE product standardization
• Pre-built and custom reporting, including finance, risk, and regulatory reporting
• Cloud-native, multi-tenant architecture that enables the system to scale as needed
• Fast implementation with data and workflows available in near real-time

Why Power Trading Needs a Purpose-Built ETRM

Power market positions shift by the hour — and sometimes, by the minute. As demand increases, regulations evolve, and products get more complex, power traders need tools that do more than capture trades. They need systems that help them stay ahead of market shifts, volatility, and risk.

That’s where a modern ETRM purpose-built for power makes a difference.

Instead of piecing together information across systems and spreadsheets, a well-designed ETRM is your system of record — capturing trades, reconciling data, tracking exposure, and exposing risks in real-time. When market conditions shift, or when a PPA actualizes differently than expected, you’re not left guessing. You already have the numbers — and the confidence — to act.

Power trading may be getting more complex, but with the right ETRM, you will be able to react with confidence — allowing you to scale your business and profit.

• A modern ETRM centralizes renewable certificate tracking across the full lifecycle: from projected to minted, delivered, and retired.
• Risk management features help prevent over/under buying, double-counting, and position mismatches.
• Automated updates to position and inventory data minimize manual errors and keep compliance reporting audit-ready.

Managing Renewable Certificates Is Complex. An ETRM Makes It Simple

Renewable energy is reshaping the global power market. That’s great for environmental and energy transition goals, but it presents a growing challenge for energy trading companies: managing renewable energy certificates and related instruments efficiently and profitably.

Certificates are complex. They’re tied to registries and trading platforms, jurisdictions, and constantly changing compliance requirements. But sellers need to optimize the value of their certificates; buyers need to meet obligations as efficiently as possible.

The biggest challenges companies struggle with include:

• Tracking inventory, obligations, and certificate attributes across multiple systems — risking certificates expiring or aging out.
• Preventing errors like double-counting or misaligned positions that can result in overpaying or undercharging, missing opportunities to optimize trades and pricing.
• Supporting compliance with automated, auditable reporting.
• Allocating inventory to obligations — often a manual, ad hoc process that’s focused on delivery only. As portfolios grow, so does the risk of missed savings and internal bottlenecks.

In many situations, the technology available to manage renewable certificate portfolios hasn’t evolved as quickly as the markets – adding a layer of difficulty to an already difficult task.

Table of Contents

• Understanding the Lifecycle of Renewable Certificates
• How ETRM Systems Capture Renewable Certificate Data
• Managing Renewable Certificate Risk
• Ensuring Accurate Renewable Certificate Position and Inventory Tracking
• Handling Minted and Delivered Renewable Certificates in an ETRM
• How an ETRM Simplifies Renewable Portfolio Reporting
• Effective Renewable Certificate Management Requires a Modern ETRM

Understanding the Lifecycle of Renewable Certificates

The renewable certificates lifecycle is complicated by accounting for two different, but interconnected, commodities: renewable energy generated and renewable energy certificates. From forecast to retirement, accurate tracking is critical — not just for reporting, but for compliance, auditability, and optimizing commercial outcomes.

Lifecycle Steps

Here’s what the lifecycle typically looks like for renewable certificates:

• Estimate generation volumes and compliance obligations for electricity-based certificates, such as RECs or GOs
• Secure forward contracts — agree to buy or sell certificates before they’re minted, based on projected supply/demand
• Record certificates as they’re minted from registries or aggregators, capturing attributes like serial number, vintage, and project details
• Allocate delivered certificates to trades and obligations — assign certificates  to meet compliance requirements or settle contractual deliveries
• Track inventory in near real-time — monitor current holdings by type, vintage, status, and ownership — at bulk or serial level
• Retire certificates for compliance closure or sales finalization
• Generate audit-ready reports — ensure jurisdictional, compliance, and vintage requirements are met and documented

Each stage of the lifecycle builds on the last, and any gaps or errors can lead to costly mismatches, compliance failures, or lost revenue.

How ETRM Systems Capture Renewable Certificate Data

Accurate data is essential for effective renewable certificate management. A renewables-ready ETRM software captures data through integrations with registries, aggregators, and market data providers — as well as via APIs, data upload tools, or simple manual entry. The key is to have a dedicated place for renewable data, such as vintage, location, serial numbers, and class data fields.

Here’s what you should expect from a modern ETRM that can handle renewables:

• Integrations with registries, aggregators, and market data providers to automate data ingestion, as well as the ability to upload trades in bulk or make connections via API
• Manual entry with validation tools to catch errors before they happen
• Custom tagging and serial tracking to group and manage certificates accuratelyA renewable-ready ETRM supports granular tracking and lifecycle management of renewable certificates, including serial-level detail, automated data matching, and project-based attribution to ensure every certificate’s lifecycle is fully documented and reconciled. By centralizing all renewable certificate data in one place, the right ETRM software ensures you always have a complete, auditable position view.

Managing Renewable Certificate Risk

Tracking renewables isn’t just about inventory — it’s also about risk exposure. Renewable certificate risk management depends on accurate policies for buying and selling certificates based on production or usage. Without a structured, automated approach, risk managers waste time reconciling mismatched data — or worse, make costly trading errors.

A modern ETRM mitigates these risks by:

• Tracking obligations against real-time inventory
• Excluding retired certificates from active positions to prevent double-counting
• Reconciling positions using forecasts, forward trades, and actual deliveries

With a clear view of renewable certificate status — projected, minted, delivered, retired — you can manage certificate risks with confidence.

Ensuring Accurate Renewable Certificate Position and Inventory Tracking

Since renewable certificate positions change throughout their lifecycle, a renewables-ready ETRM supports the accuracy and reliability of your position and inventory data through its audit trails, automated data loads, and matching capabilities. It reduces the risk of position mismatches and helps keep your renewable inventory accurate.

It provides audit trails for every certificate movement, from projected to minted, delivered, and retired, for RECs, RINs, RGGIs, and LCFS credits. Automated updates as certificates are traded or used to minimize spreadsheet errors, so you gain significant protections compared to spreadsheet tracking. Certificates can be matched with their associated commodities to categorize them for reporting.

With a modern ETRM, you can match renewable certificates to their associated trade(s) and commodities, keeping track of certificates in high-volume or bundled contracts along with their outlooks and exposures. Custom tagging and serial number tracking enable bulk and granular certificate tracking within these contracts.

Handling Minted and Delivered Renewable Certificates in an ETRM

Once certificates are minted, they must be properly accounted for and tracked within the system. An ETRM built for renewable certificate management connects to registries and aggregators to bring in structured certificate data – automating lifecycle tracking from creation to retirement.

• Minted certificates are downloaded from registries and recorded as inventory
• Delivered certificates are linked to trade volumes or obligations, ensuring accurate lifecycle tracking
• Status updates flow through the system, keeping compliance reports audit-ready
• Transfer and retirement instructions can be generated for registries

Molecule models all key certificate attributes, resulting in complete and accurate valuations throughout the lifecycle. It tracks certificates as physically delivered inventory (both in bulk and at the serial number level), which can then be matched against obligations to optimize the value of your portfolio and give accurate current and forward position reports.

The result is accurate and up-to-date inventory data for analytics, reporting, and auditing.

How an ETRM Simplifies Renewable Portfolio Reporting

Regulatory and compliance reporting for renewables is complex and time-sensitive. A renewable-ready ETRM reduces manual work by automating position and inventory reports so you always know your exact holdings. It offers custom API exports and integrates with BI tools, GLs, and ERPs.

Specialized reporting built for renewable certificates provides insight into positions, inventory, obligations, vintage, and REC status – keeping you ahead of compliance deadlines without last-minute data scrambles.

Effective Renewable Certificate Management Requires a Modern ETRM

With the growing variety of renewable certificates — each with distinct vintages, compliance rules, and market dynamics — companies trading renewable energy need an ETRM that can reliably track them through their entire lifecycle with audit trails for every movement, including trading, forecasting, minting, allocating, retirement, and reporting.

Without an ETRM built for renewables, companies can easily lose track of what certificate they are holding, which have been allocated, and what certificates they need to purchase to stay compliant, leading to position mismatches, over- and under-buying, and lower profits.

Managing renewable certificates is complex, but a renewable-ready ETRM provides clarity with reliable, auditable tracking and reporting — giving you the confidence to stay compliant, fulfill obligations, and keep your business moving forward in an increasingly complex market.

Editor’s note: This blog was originally published in January 2024 as "How Do ETRM Systems Handle Renewable Credit Management?". It was extensively updated and republished in July 2025.

• Interoperability is becoming increasingly important as the amount and speed of trading-related data increases.
• Many trading and risk systems weren’t built for real-time interoperability — making integration harder than it looks, even with cloud and APIs.
• Modern ETRMs built for interoperability enable faster, more confident decisions — and give trading orgs a competitive edge.

Disconnected systems don’t just slow down IT — they slow down your entire trading organization. They create blind spots, inefficiencies, and hidden costs that add up over time, slowing down trading and decreasing profits. You can’t make smart, fast decisions if your systems don’t talk to each other.

Interoperability between systems is often regarded as “the Holy Grail” of ETRM software. Even with cloud technology and APIs, integrating trading and risk systems is hard. Why? Because data is messy, and data formats aren’t standardized. Many systems weren’t built with interoperability in mind.

But with a modern ETRM and a clear strategy, you can achieve ETRM interoperability and trade with more confidence.

Table of Contents

1. Why Is ETRM Interoperability So Hard?
2. The Hidden Costs of Disconnected (or Poorly Integrated) Systems
3. Interoperability Leads to Smarter, Faster Decisions
4. Best Practices for Achieving Interoperability
5. What ETRMs Need to Support Interoperability
6. When Risk and Trading Systems Work Together

Why Is ETRM Interoperability So Hard?

With more ETRMs boasting cloud technology, APIs, and modern data platforms, it seems like interoperability challenges should be a thing of the past.

So why is it still so hard?

The truth is, most trading and risk systems weren’t built to talk to each other — and certainly not in real time.

Older ETRM systems and risk platforms weren’t built to talk to modern, cloud-based solutions, access data lakes, or integrate with analytics tools. The data in these older ETRMs was built for use in one isolated system — and it shows.

Each ETRM has its own naming conventions, timestamps, and trade lifecycles, which creates errors and inconsistencies when you try to connect data across different software systems. Even the most tech-savvy users in energy trading companies can struggle to access clean, usable data from legacy systems.

However, even when vendors want to work together, internal processes, priorities, and tech stacks don’t always align.

“It seems like integrating systems should be easy—cloud, APIs, all that good language—but it’s actually more than just a technical issue.” – Gary Vasey, Partner & Managing Director of Commodity Trading Advisory

The result is hours lost to spreadsheet workarounds, mismatched records, and double-checking numbers nobody fully trusts. In short: you get systems that look connected, but still act like silos.

The Hidden Costs of Disconnected (or Poorly Integrated) Systems

Poorly integrated systems impair decision-making. When data is siloed, traders and risk managers often make decisions based on information that’s outdated or incomplete. As a result, they may miss opportunities — or worse, act on the wrong ones.

Systems that aren’t integrated require manual reconciliation, increasing the risk of human error. People are not computers — they make mistakes, especially when transposing or manipulating data. Every handoff is a chance for something to slip through the cracks.

Integrating systems manually is also inefficient. Teams that spend hours integrating data can’t devote time to higher-value work, like analyzing new opportunities, assessing market trends, and enabling the company’s growth. That’s a waste of time and talent.

Disconnected systems also increase compliance risk. Without system-wide consistency, it’s harder to maintain audit trails and ensure regulatory compliance. And if an energy trading company can’t prove regulatory compliance, they may incur hefty fines, restrictions on trading activities, severe damage to its reputation, and potential criminal penalties – including jail time.

These hidden costs won’t show up on a balance sheet, but they compound over time — and ultimately weigh down speed, clarity, and confidence across the business.

Interoperability Leads to Smarter, Faster Decisions

ETRM interoperability enables better decision-making. Traders and risk managers can quickly react to new information while it's still fresh by getting accurate, real-time insights instead of waiting for batch processing or manual data reconciliation.

Traders can act with confidence and react quickly to market shifts without second-guessing data integrity. A single, real-time portfolio view prevents firms from over- or under-hedging risk, improving both hedging and portfolio management.

“You could think of it like an ETRM system telling you exactly where you are, an analytic system telling you where you might go, and risk systems, making sure that you can get from one place to the other.” – Ben Lafleur, Head of Professional Services, CubeLogic

When all systems are fully integrated through trading and risk management automation, risk teams do not have to work with IT to manually link systems or troubleshoot missing or inconsistent data. Trading system integration removes the back-and-forth, reduces operational friction, and saves time.

With clean data and smooth workflows, teams can focus less on managing tech and more on shaping strategy. This makes risk management more effective, efficient, and less costly.

Best Practices for Achieving Interoperability

Achieving ETRM interoperability requires trading system integration and risk platform automation. To fully integrate these systems requires a few steps:

• Map out critical data flows. Identify what data needs to move between systems, in what format, and at what granularity.
• Use APIs and automation. Minimize manual file transfers and spreadsheets that are slow, error-prone, and not scalable.
• Standardize data formats. Consistency in timestamps, trade IDs, and reconciliation rules prevents discrepancies across platforms.
• Continuously test and optimize integrations. Use regular stress-testing and performance monitoring to fine-tune integrations and prevent bottlenecks. Choose modern integration technology – like Zapier or iPaaS – to make the process easier.
• Adopt a data ecosystem approach (if needed). In cases where an enterprise doesn’t have one system, extract raw data into a centralized repository (like a data lake) for a full portfolio view.

Energy trading companies need to understand how their current systems and data flows work to integrate trading-related systems successfully. A comprehensive view of current processes reveals which systems need to be updated and which data needs to be standardized to ensure long-term success.

What ETRMs Need to Support Interoperability

Modern ETRM systems must be built to support trading system integration, not just to capture trades. They must be designed to integrate with both current and future systems to support automation, speed, and scale.

Here are the key capabilities to look for in an ETRM built for true interoperability:

• API-first architecture. Enable real-time data flow, allowing your trading and risk teams to focus on markets, not IT fixes (bonus points if it has Kafka-like streaming abilities).
• Scalability for high-volume data processing. Handles large datasets efficiently, ensuring real-time, reliable risk and trade data.
• Automated reconciliation and validation. Reduces manual workload and flags discrepancies early, keeping risk data clean and trade execution fast.
• Configurable data models. Flexes with your business as it grows — without costly reengineering.
• Cross-platform compatibility. Connects with risk, credit, and analytics systems you already know, use, and trust.

A modern, fully integrated ETRM system provides the real-time visibility and accuracy needed to enable better trading decisions, faster. With the right architecture, you can replace manual processes with clean, connected data — so you can take advantage of new opportunities and avoid risky ones.

When Risk and Trading Systems Work Together

Interoperability is a core attribute of systems built for modern energy trading. When systems work together, companies gain a competitive edge: faster decisions, fewer errors, and greater confidence.

Start by making sure your ETRM has the APIs, flexibility, and scalability to fully integrate with your other trade-related systems. Without a modern ETRM built for interoperability, you’ll end up relying on costly workarounds that create a cycle of continuous reengineering to ensure the system remains fully integrated.

A modern ETRM system provides what legacy systems can’t: connected data you can trust, clean workflows, and the confidence to move fast.

Companies that modernize their systems for interoperability aren’t just reducing risk — they’re building smarter systems, faster operations, and a competitive edge that compounds over time.

1. The energy transition is accelerating, creating both opportunities and risks.
2. Renewable energy introduces volatility, complex pricing, and regulatory challenges.
3. Modern ETRMs are essential for managing risk, ensuring compliance, and handling renewable portfolios.

The Energy Transition Is Here (And It’s Complicated)

The renewables market isn’t slowing down — but outdated systems are. As energy markets grow more volatile around the globe, the tools companies use to track and manage renewable portfolios need to move faster than ever to keep up.

This means that modern ETRM systems are no longer optional; they’re essential. They provide a reliable system of record that tracks transactions, provides a pro forma view of financial performance, and ensures compliance for complex renewable portfolios. Without modern solutions, businesses risk falling behind in a market that won’t wait for them to keep up.

So how can renewable energy producers and traders stay ahead — and uncover new opportunities — in a market that keeps changing?

Table of Contents

1. What's Driving the Increased Demand for Renewables?
2. The Challenges of Renewable Energy
3. How Modern ETRMs Support Renewable Power
4. The Future of ETRMs
5. Modern ETRMs Help Tame Renewable Energy Volatility

What’s Driving the Increased Demand for Renewables?

Investment in renewable energy is surging due to both environmental goals and economic imperatives. But it's not just about what's being traded, it's also about how companies are managing their portfolios.

• Energy Security: Nearly 80% of the world’s population lives in countries that import fossil fuels, making them vulnerable to geopolitical tensions. Local renewable sources such as solar and wind reduce reliance on imports.
• Cost Declines: The cost of electricity from solar power fell by 85% between 2010 and 2020, with similar reductions in wind power costs.
• Decarbonization & Climate Goals: Reducing greenhouse gas emissions is a major driver for renewable energy adoption. With fossil fuels being the largest contributor to global climate change, transitioning to renewables is essential for meeting net-zero targets. Countries and corporations alike are accelerating decarbonization efforts, making renewables a critical part of future energy strategies.

The Challenges of Renewable Energy

While switching to renewable energy can deliver environmental, geopolitical, and even financial benefits, renewable energy production comes with its own challenges — especially when it comes to tracking and managing complex power portfolios.

• Generation is unpredictable. Unlike fossil fuels, many types of renewable generation are inherently volatile. Both wind and solar only produce energy at certain times of day and are affected by weather conditions, leading to fluctuating hourly production capacity. This volatility creates risk and makes forecasting difficult.
• Power markets move fast. Power markets are priced hourly, or even sub-hourly, to account for variations in demand, and the need to keep the grid in balance. There can be a large difference between peak and off-peak pricing and some nodes will even regularly experience negative pricing. A lack of up-to-date insights means traders risk missing profitable opportunities or mismanaging their exposure.
• Legacy systems and spreadsheets aren’t built for the complexities of renewable trading. Many companies still rely on outdated systems that lack automation, real-time tracking, and reliable position visibility — so it’s too difficult to track renewable attributes like vintages, expiries, and offsets accurately. Instead of focusing on making smart decisions, teams just end up buried in manual processes.

How Modern ETRMs Support Renewable Power

Modern, scalable ETRMs capable of handling the complexities of renewable portfolios are essential to staying competitive in today’s energy markets.

Advanced Data Management

Modern ETRMs have specialized functionality to handle the large, complex datasets associated with renewable portfolios and power purchase agreements (PPAs), which often involve tracking tens or hundreds of thousands of data points across multiple energy and pricing sources.

These systems offer automated data flows through APIs and integrations, and flexible data models to handle evolving demands from consumers, counterparties, grids, exchanges and regulators.

Portfolio and Risk Management

Modern ETRMs help market participants manage risk by enabling them to assess and counteract market, credit, and operational risks associated with energy trading activities. By providing reporting based on reliable, up-to-date data, in a single system, the ETRM allows users to identify potential exposures, implement hedging strategies, monitor market fluctuations, and ensure compliance.

Renewable Certificates

In addition to regulatory demands, companies that trade renewables must also manage the complexity of production-linked certificates and obligations. These certificates, including renewable certificates and allowances, offsets, and derivative instruments, have unique contracting, eligibility, and pricing challenges. ETRMs with advanced capabilities for renewable certificates and managing them through their entire lifecycle.

Key features of modern ETRMs for renewables include:

• Automated processes: Match and allocate physical certificates with the commodities that generated or consume them and capture type-specific fields, such as eligibility, class, and expiry
• Lifecycle oversight: Optimize renewables trades and manage the full lifecycle of renewable instruments
• Certificate management: Track certificates down to the serial number level to accurately manage inventory and deliver a comprehensive audit trail of all certificate proposals and linked demand retirements
• Custom reporting ability: Including how credits offset carbon positions, the value of inventory, allocation gaps, regulatory compliance, and more

Legacy systems do not have this specialized functionality, making them ineffective tools for managing all the intricacies of renewable energy trading. In contrast, modern ETRMs are modular, agile, and robust solutions designed to keep pace with today’s energy markets.

The Future of ETRMs

Demand for renewable energy continues to grow – especially with advances in battery technology and growing power needs for data centers This will add complexity to an already complex, volatile market. Demand for new ETRM functionality will also increase in a renewables-driven economy, requiring ETRM systems to evolve to support complex portfolios with large datasets.

To keep up with this constant pace of change, ETRM systems must be scalable, agile, and reliable. Therefore, modern ETRMs need to be cloud-based and multi-tenant to easily model new lines of business.

Modern ETRMs Help Tame Renewable Energy Volatility

Modern ETRMs can support energy companies as they transition to a more diverse energy portfolio, ensuring regulatory compliance and handling the complexities of diverse renewable commodities. These modern systems have customized modules to manage renewable instruments and are built to handle more complex pricing, forecasting, trading, and risk mitigation.

Energy markets will continue to evolve as countries seek to reduce carbon emissions and increase energy independence. New technologies, such as more efficient industrial batteries, will accelerate the energy transition.

Companies that want to stay ahead must invest in future-focused ETRM solutions as part of their renewables trading strategy, so they can ensure they have the forecasting, tracking, and reporting functionality they need to evolve with energy markets.

1. Managing a power portfolio requires dealing with large, complex datasets — not ideal for spreadsheets.
2. Manual data entry, version control, and reporting delays make spreadsheets a risky choice for managing energy trading and risk.
3. A future-ready ETRM eliminates common spreadsheet limitations, delivering a single source of truth with real-time visibility.

It’s 2025, and spreadsheets just can’t keep up with the speed of today’s power markets.

Relying on spreadsheets to manage a complex power portfolio is a gamble at best. A delayed trade reconciliation, an outdated P&L, or an inaccurate position could put your business — and your bottom line — at risk. And yet, many companies still rely on spreadsheets as their system of record for power portfolios.

In this blog, we’ll break down the biggest pitfalls of relying on spreadsheets for a complex power portfolio and how modern ETRMs are built for the future of energy trading.

Table of Contents

1. The Limitations of Spreadsheets in Power Trading
2. Spreadsheet Mistakes Can Cost Millions
3. Future-Ready ETRMs Are Built for Power Portfolio Management
4. Ditch the Spreadsheets to Save Time, Cut Risk, and Increase Profit

The Limitations of Spreadsheets in Power Trading

Spreadsheets like Excel are useful when dealing with smaller datasets — but when managing a complex power portfolio, their limitations are obvious. Large datasets – such as granular forecast data and multi-decade, hourly PPAs – overwhelm spreadsheets, making them slow, error-prone, and nearly impossible to manage at scale. With hundreds, thousands, or even millions of data points to track, spreadsheets struggle to keep up with the speed and complexity of today’s power markets.

If you’re using spreadsheets to manage a complex power portfolio, you’re putting your profit margins, reliability, and reputation on the line. Here’s why:

• 94% of spreadsheets used in business decision-making contain errors. That’s not a minor issue — it poses a serious risk of financial losses and operational mistakes.
• Manual data entry is notoriously slow and inaccurate. Validating spreadsheet accuracy requires a lot of time and effort, slowing decision-making down when time may be critical.
• Energy trading data is constantly changing. The time spent manually entering and reconciling data can result in analyses and reports that are outdated before they are even published. Real-time analysis is impossible because the process is too slow.
• Spreadsheets suffer from version control. Team members can share or edit a spreadsheet without realizing that other members of the team are also editing a different version of the spreadsheet. There is no single system of record for the business, and teams may make suggestions or take actions based on contradictory information in their individual spreadsheets.
• Spreadsheets don’t have automatic compliance features, so compliance must be managed manually as well. If there are multiple versions of spreadsheets, companies must be sure compliance reporting is based on the “correct” one.

Spreadsheet Mistakes Can Cost Millions

One wrong spreadsheet formula once cost JP Morgan $6 billion. Energy risk management using spreadsheets risk similar catastrophic financial consequences resulting from mismanaged risks, incorrect settlements, and unprofitable transactions.

Spreadsheets inhibit compliance, increasing regulatory and compliance risk. They do not provide a comprehensive audit trail and lack data validation. Because of the lack of version control, data is outdated, disparate, and vulnerable to security breaches.

Data silos and the time spent manually entering and manipulating data slows the business down, making the company sluggish to act or respond. It’s not a speed that can match today’s market, so lost opportunities are common.

Future-Ready ETRMs Are Built for Power Portfolio Management

Spreadsheets may be cheap and user-friendly — but they weren’t built with managing high-volume, real-time power trading data in mind. Future-ready ETRMs are built with power trading capabilities in mind, so your team will spend less time fixing errors and more time making smarter, faster decisions.

Ditch the Spreadsheets to Save Time, Cut Risk, and Increase Profit

Spreadsheets are a great tool when used properly; however, they were not designed for modern energy risk management. Excel was first released in 1985 — 40 years later, spreadsheets just can’t keep up with increasingly complex power portfolios and constantly changing energy markets.

Replacing spreadsheets with a future-ready ETRM platform speeds up the entire process, improving accuracy and flexibility so companies can stay on top of the market and better manage risk. ETRMs for power portfolios help ensure regulatory compliance as well, a feature that is beyond the scope of any spreadsheet. The entire process, from deal capture to invoicing, is more secure, faster, and more accurate with a modern ETRM system.

Spreadsheets may have been enough – for a while. If you’re still using spreadsheets to manage your portfolio as your trading organization grows, though, you’re already behind — and leaving money on the table. It’s time to upgrade.

Rising power demands, a push for renewable sources, global political shifts, and technological advances all mean the energy market is experiencing a time of unprecedented volatility. While traditional energy markets were dominated by oil, gas, and centralized grids, it’s evolving into a diversified ecosystem to include solar, wind, and battery storage. This sets the stage for a new landscape of market dynamics.

EnerWrap is a free daily newsletter that helps professionals navigate the complexities of the energy markets with data-driven insights and visualizations across sectors like oil, natural gas, solar, wind, and battery storage. EnerWrap’s founder, Jeff Davies, is an energy analyst and trader with over 15 years of experience managing and investing in energy credit.

We sat down with Jeff to dig deeper into what’s driving these market shifts, emerging trends, and the biggest misconceptions in energy today.

The U.S. power grid is changing rapidly. What does that mean in terms of reliability, and is that change sustainable?

Jeff Davies: The data indicates no significant change in reliability. What's changing is really primarily generation capacity through solar buildouts, through battery buildouts. At the end of the day, grids go down a lot because of transmission issues. The problem is that in the U.S., there’s a three to five-year wait to get into an interconnection queue to build capacity. So we have this massive demand growth, but supply might lag because there are these regulatory traps and the challenges just to get new transmission built or to get a new power plant tied into the grid. So that's a big trend to watch, but I don't think reliability yet. We haven't seen it here. If you look at the daily data and hourly data, we set record after record after record in 2024, in the summer of 2024, peak power.

I think we're going to see some additional gas plants built. And what we're seeing is nuclear plants that were mothballed coming back. There are some small modular reactors being built in Wyoming. I think you see more of that as well because it's very hard to find clean power. And if you think about who the largest users of AI are, it's the hyperscalers: that means Apple, Microsoft, Google, Amazon and Meta/Facebook. Those are the main users of graphic GPUs and those types of things that are driving AI power demand. And all of those companies have green mandates, so a lot of this demand growth will inherently be forced to come from green energy because of the policies that those companies have in particular.

I think we’re going to see continued capacity growth, and time will tell if my bigger worry is supply and demand imbalance. I think once we get to where we want to be, I'm not as concerned about reliability.  

Adding renewables to the U.S. energy grid is outpacing other energy sources. Despite this, there’s a lot of uncertainty about whether we’re on track to triple renewables by the end of the decade. Do you think this goal is achievable?

Jeff Davies: I think it's achievable, but the political environment may cause delays. I think it’s doable in a perfect world where people don't debate these issues and just want to get it done, but that's not the world we live in.

I think there are risks to [the US energy grid outpacing other energy sources]. I personally continue to be surprised by the amount of growth. As I’m curating my newsletter, there were weeks where every day brought news of a new solar or battery project. So this is happening quickly, and on a massive scale. I think it’s going to continue.

We’re seeing a massive trend in data centers being built to keep pace with AI. There’s also a huge renewable energy push. Can these two truly coexist?

Jeff Davies: I think they can coexist because they're going to grow naturally at a similar pace. I'd be more concerned if we were going to build a bunch of data centers and we don’t even know where we're going to interconnect into, and where that interconnection is going to tie into what type of power. But nobody does that practically.

What are the biggest trends you’re seeing in the energy markets today?

Jeff Davies: There are a few trends that are widely discussed in power markets. One is the increasing power demand, especially in the U.S., but also globally. Some of the forecasts for AI suggest U.S. power demand could rise 50% over the next decade after being flat for 20 to 30 years. These are big changes.

On the supply side, there is massive growth in renewables. The biggest story is the shift in supply and demand, and I’ve been highlighting solar and battery charge as the big stories. I think natural gas is an underrated story. It continues to increase demand growth of capacity and generation, in particular. But it's really a solar and battery story. If you look at the kind of capacity being added in the U.S. that's on the order of magnitude of 80% of it, it’s solar and battery. Battery storage, in particular, is becoming a bigger story. It has kept prices lower and is starting to remove volatility from energy prices too, which is good for consumers.

What is the biggest misconception about today’s energy markets?

Jeff Davies: Given the environment we're in, who is president is considered super important — but I don’t think that’s the case. We get into debates and arguments, even within the energy industry, about what will happen if one president or another is elected. But the reality is the energy industry is the largest, most capital-intensive industry on the planet. Everyone uses it, and no single person can change it. The market is that large, that interconnected, that complex.

The politics of it all is not truthful. This is an industry. I look at the oil and gas industry, and even with a lot of layoffs recently, we keep hitting all-time high production through efficiencies. Boiling down how the energy markets are influenced by one human being is dismissive of all the hard-working people in those industries.

Where do you see the future of energy markets going?

Jeff Davies: What's fascinating about energy markets is there are so many variables that impact them — geopolitics, macro, micro, country-specific factors. It's a market that's going to have a significant change, but these are such large scale changes that's going to take decades. So it really depends on timing.

I think in the next couple decades our power portfolio will be significantly renewable, which will have massive impacts on oil demand. I do think oil demand is likely peaking soon, so we're going to be in this unprecedented market of increasing power demand, increasing power supply, decreasing oil demand. I think that’s going to create a lot of volatility around energy markets.

What inspired you to start EnerWrap?

Jeff Davies: A lot of people are oil and gas people, renewable people, energy people, power people, or midstream people. Having invested across all of these subsectors gives me a unique perspective. I'm trying to bring an all-encompassing perspective to what's happening across energy markets broadly and what you should be aware of from the news and data.

It’s why EnerWrap’s tagline is “Data-Driven Energy Insights.” I see a lot of bias in energy reporting and analysis, especially in the current political environment. For example, someone claimed energy prices dropped 50% the other day — there's no truth to that, and there's not a lot of truth to a lot of things that people talk about in energy. So if you just provide the data, the data is the truth.

You’ve created many of the data visualizations on EnerWrap. Tell us more.

Jeff Davies: EnerWrap focuses on creating accessible data visualizations because most people don’t want to read pages of text. I've found success in letting the data tell the story with visualizations.

It’s a Google add-on called Wrapify. It’s basically a tech stack to tie into various energy data APIs — Grid Status, EIA, Our World in Data, Ember. In just a few clicks, you can pull global data, create visualizations, and automate updates that you can turn into either a daily update or a PDF around those data visualizations.

Wrapify integrates Datawrapper, which is an independent company that has a great data visualization platform. What Wrapify allows you to do is pull whatever data you want into the sheet, wrangle it however you need for whatever chart, map, or table you want, and then send it to the sheet into this cloud-based service. It also has a number of data API integrations, so you get access to millions of data sets at your fingertips.

As a self-proclaimed BBQ aficionado, what are your best BBQ tips for those who want to improve their pitmaster skills? What are your go-to BBQ spots in Houston?

Jeff Davies: I used to live up in north Houston, and my favorite spot was Tejas Barbecue. I personally think that's one of the better barbecue spots here in town. I’d also recommend Pinkertons for their ribs. I used to have a pipe smoker, but now I'm down to just an electric smoker.

If you have a smoker, smoke some baby back ribs. If you don’t, cut the ribs into single pieces, place them on a baking sheet with a wire rack, and cook them at 350–400°F for about two hours with some spice on them. Then take one part honey, one part soy sauce, one part gochujang, and mix that together, get it warm, maybe with some garlic and ginger. And then you have Korean-inspired sticky ribs for yourself. So put it on the ribs and you're good to go.

Modernizing risk operations is no longer a “nice to have” — it’s essential for staying competitive in shifting markets.

As companies prioritize modernization, the focus is shifting toward streamlined software solutions offering enhanced speed, usability, and direct data access. The results of our first-ever ETRM/CTRM Transformation + Modernization survey highlight the evolving expectations of today's trading organizations and the demand for more agile, robust, and reliable systems.

We’re going to dive into the biggest takeaways from the survey, plus you can also access the full 2024 ETRM/CTRM Transformation + Modernization report for a comprehensive analysis and exclusive commentary from experts across the energy and commodities industries.

Table of Contents

1. This year’s theme: speed up to keep up
2. Survey methodology
3. Key findings: modernization in 2024
4. Top priorities for risk managers
5. Challenges to modernization
6. Are ETRM/CTRMs supporting trading needs in 2024?
7. Resources

This year’s theme: speed up to keep up

It’s a volatile market out there.

Trading organizations are feeling the push to update their operations as a result of evolving behaviors and policies. Factors like supply chain instability, technological advancements (like the AI surge), and the global energy transition underscore the necessity of adapting — swiftly — to survive in a dynamic market.

“When you think about risk, there’s realized volatility which can be measured and seen, and then there’s unrealized volatility, which is really the unknown in which most organizations, from a risk perspective, you try to manage.” – Jeff Davies, Founder, EnerWrap

And there’s no sign of slowing down. As a result, agility and analytics are top of mind for many trading organizations, and will continue to play a key role in managing risk operations.

Companies are increasingly driven to modernize not just to gain a competitive edge but also to tackle real challenges that their current systems may struggle with—such as managing new instruments or large amounts of data or getting more accurate reports faster. This is where automated, cloud-native, multi-tenant software solutions will shine, helping to solve problems and save time while improving risk operations.

The markets are changing, and so are the expectations for what a modern ETRM/CTRM platform should be. There’s a significant opportunity for modern ETRM/CTRMs to align with companies’ changing needs and objectives to support key operations for today, tomorrow, and the years ahead.

“While market volatility is important, it’s really that organizational shift column is the tail that I feel wags the dog. As organizations focus more and more on sustainability, we see this move to more complicated power contracts, higher quantities of them, and really needing to build that into — and this speaks to the diversity of the commodities… the ability to capture those transactions into the system.

“And then on the flip side of things, as we think about data centers out there, the AI movement, the computational needs and the amount of data centers out there is making the world power hungry, which starts a whole new level of types of transactions out there. So those two things are really, what I’m seeing, drive the energy transition at this point in time.” – Michael Barrett, Managing Partner, EY

Survey methodology

Over 200 participants in the commodity market responded to our survey. Respondents represented small (under $1 million), mid-size, and large organizations (>$1B). The data gathered represents companies that trade all types of instruments, ranging from oil/petroleum products, power and gas, LNG, biofuels, metals, environmental/renewables, and more.

Key findings: modernization in 2024

Here are the biggest takeaways from our 2024 ETRM/CTRM Transformation + Modernization Report.

• 90% of all respondents report planning a modernization initiative or having one currently underway
• Modernization is a top priority across all company types and sizes
• 100% of bankers/brokers and renewable developers are planning to modernize
• 75% of all other company types have modernization plans
• Renewables developers, consumers, and advisory firms are the furthest along: nearly 40% have modernization initiatives currently in progress.
• Nearly 100% of companies with $500 million to $1 billion have a modernization initiative underway, while 60% of smaller companies (under $1M) are planning one
• Despite the need to modernize, cost and executive buy-in are the greatest challenges to modernization
• 21% of the smallest companies don’t know where to begin when it comes to modernization

Top priorities for risk managers

When asked about which risk management priorities will not change over the next 5 years, the response was overwhelming: nearly 70% of all responses stated agility and analytics.

It makes sense: both agility and analytics are fueled by the need for speed. Today’s trading operations demand agile, automated solutions to navigate evolving business processes effectively, ensuring faster decisions and more accurate risk assessment.

The commodities market is moving towards algorithmic or automated trading — so, speedier trades need more agile systems. Automated trades happen in seconds, so reporting needs to be just as fast. Plus, with tech advancements like AI and real-time data, quick analysis of trade data and report creation that takes seconds, instead of hours, are a must.

In short: in the traditionally slow-moving energy industry, companies are now realizing that modernization is no longer a shiny upgrade option… it’s essential for their survival.

Challenges to modernization

While there's a lot of confidence in kicking off modernization efforts, cost and executive buy-in are the biggest modernization challenges across all respondents.

From smaller teams with less institutional knowledge, to enterprises with embedded legacy systems, these challenges are being felt across organizations.

Are ETRM/CTRMs supporting trading needs in 2024?

80% of users feel their current system doesn’t support all their necessary business practices or is too slow, and a further 21% say it doesn’t handle everything they trade. This signifies the need for more adaptable and scalable solutions to keep up with their evolving trading needs.

Our findings were consistent across all company types, with consumer companies showing a strong bias at 45%. Traders and advisory firms, particularly, faced challenges with existing systems, impacting daily operations and market entries. Traders highlighted the system's slow performance, with 57% reporting difficulties.

Legacy ETRM/CTRM systems are too slow

Outdated ETRM/CTRM systems can be sluggish, taking hours to generate risk reports on positions and exposure. Frankly, that’s not good enough in today's fast-paced environment. Now, data is almost immediately accessible, and analytics can be run in seconds.

Efficiency is at the core of the desire for a modern ETRM/CTRM system, prompting a demand for streamlined data input, real-time analytics, and user-friendly interfaces for precise price risk assessment. Automated systems with a unified record system ensure speed and reliability, enabling quick data access and analytics within minutes.

Most desired features in an E/CTRM

In an open-ended question, we asked survey participants to tell us what functionality they would like to see (in an ETRM/CTRM) that isn’t available to them now.

There’s a clear underlying theme for desired functionalities: namely, speed and automation, user-friendliness, deal entry, integrations, and the ability to handle various instrument types. This highlights speed and agility as top priorities while also underscoring the finding that many ETRM/CTRM systems in use today fail to support all the business practices organizations need to thrive.

Resources

• 2024 ETRM/CTRM Transformation + Modernization Report
• Webinar: The Need for Speed: How Evolving Markets Are Impacting Risk Management

• Understanding current and future needs will help you choose the right ETRM/CTRM software solution
• Clear expectations enable smooth implementations
• Include stakeholders from the beginning and gain their support for any ETRM implementation

As you are likely well aware, implementing a new ETRM solution is a big undertaking. It often follows several months (or more) of assessing needs across various stakeholders, weighing options, interviewing vendors, and convincing top management that the investment makes sense.

Choosing the right system, aligning all stakeholders, and moving forward consumes a lot of time and energy (not to mention the significant financial investment), so getting your ETRM implementation right is crucial.

…No pressure, right?

The good news is there are ways to make sure it goes as smoothly as possible. Here’s what you need to know.

10 Things You Need to Know Before Implementing a New ETRM Software System

1. Project Goals
2. Be Clear About Your Needs
3. Scope and Pricing
4. Total Cost of Ownership
5. ETRM System Security
6. Integrations With Other Systems
7. Trading Needs Covered for the Full Lifecycle
8. Business Process Impact
9. Project Members
10. Regulatory and Compliance Obligations

1.   Project Goals

First things first: no company will buy into the idea of investing time and money finding — and implementing — a new ETRM system without a solid reason.

Everyone involved in the implementation needs to understand the goals of the new project, and that begins with reviewing and outlining the limitations of your current system. Is it too slow? Difficult to use? Doesn’t handle everything you trade? Be honest here.

Once you understand the limitations of your current system, outline and verify what you expect to achieve with a new ETRM system. Make sure everyone — and we mean everyone: stakeholders, traders, risk managers, IT, etc. — understands why a change is not only necessary, but also beneficial to them and the organization.

2.   Be Clear About Your Needs

A modern ETRM system will provide new functionality, including faster, more reliable, and more robust reporting; automated trade management (like deal capture); the ability to handle different assets and instruments; and real-time position reports.

To get the right solution for your company, it’s important to know how you plan to use your new ETRM system works. While many of the provided features overlap, every ETRM vendor offers something different.

• Evaluate which features will benefit your organization and team
  When you begin searching for a new ETRM system, you may have a wish list of all the features you want. However, thanks to budget constraints, technical limitations, or even your evolving business, the reality may require some compromises. Prioritize the features that are most important to your business over shiny bells and whistles you may never use.
• Create a list of reports your team will need, both now and in the future
  Different ETRM systems offer a variety of reports, such as trade history, inventory movements, real-time position and exposure, pricing (and market volatility), VaR (current and over time), profit margins, and more. Matching the reports you need with the reports an ETRM system provides is essential.
• Outline the processes that will change
  A new ETRM system helps improve efficiency in part through process improvements. Operations that used to be handled in separate systems – including scheduling, invoicing, settlements, trade capture, risk management, and inventory management – can now be managed on one platform, requiring completely new processes.
• Ensure the ETRM vendor sets up the system according to your needs and provides the necessary training
  Getting the most out of your new ETRM system requires understanding how to use it. The right training will ensure your team is up and running on the new system quickly and effectively.

3.   Scope and Pricing

If you have an ETRM vendor (or vendors) in mind, have them explain exactly what an implementation requires. Have them walk you through every integration, system requirement, etc., to ensure you have a clear, accurate vision and understanding of cost for what they will do. Once everyone agrees on the goals, the vendor, and the implementation timeline, stick with it.

• Drill down from goals and needs to specifics. Map out the key processes, inputs and outputs in sufficient detail to start planning for team size and time commitment. This will also aid your vendor in quoting pricing.
• Be clear about “must haves” vs “nice-to-haves”: limiting scope is a key pricing lever.
• Identify all the critical reporting and data flows that must be replaced. Gather input/output file specs and report layouts. Identify people and functions that expect output from the ETRM, and how flexible they will be in their expectations.
• If you are implementing multiple commodities, trading desks, or business units, each of them will need an individual scope — and a plan for what is to be implemented in sequence or in parallel.
• Be sure to include your audit and control needs as part of the scope from the beginning.

4.   Total Cost of Ownership

Along with a clear vision of project scope, knowing the total cost of a new system is important. Here are some items after the initial software purchase:

• Professional services: Data migration (especially when moving from multiple systems to a centralized system), system integrations (including fees to other vendors if required), etc.
• Ongoing routine maintenance, including upgrades and patches
• Employee training, support, and onboarding
• Updates to current infrastructure (legacy systems often run on older computers and servers, so you may need to upgrade your IT infrastructure to run the new system. Excel, for example, takes very little computing power to run.)
• Updated internet bandwidth
• Increased data security measures (if you plan to move to a cloud-based, SaaS system)

5.   ETRM System Security

In the first six months of 2024, the United States saw some of the biggest, most damaging data breaches in recent history. ETRM systems store sensitive and proprietary data, so any new system must have the highest level of data security possible.

Review potential vendors’ security measures and any necessary certifications (such as SOC) to ensure they’re up-to-date and comprehensive. We also recommend involving your IT department in the selection process to understand their security requirements for new systems.

6.   Integrations With Other Systems

An ETRM that can integrate data with existing systems boost your business value with significant time savings, reliable access to information when you need it, and more. Here are some key considerations:

• You will likely need your system to connect with an exchange (or ISO) to bring in your trades. For OTC trading, you may be able to connect to an internal system, or use spreadsheets to upload.
• You may require a market data source for daily marks, or your internal built (proprietary) curves, as well as any additional position/valuation data sources.
• You may want to integrate with an accounting system to pass MTM or settlement records to your P&L or to generate invoices.
• You may need to connect to a BI tool (or Excel) for additional reports and analysis.
• Other options may include an asset management system, scheduling system, logistic system, etc.

Before you begin an implementation, you need to know which system(s) the new ETRM system needs to integrate with and how those integrations will work. Be sure to gather technical requirements for each of the integrations (including APIs, data formats, and protocols required), talk with vendors and internal resources to determine what work is required, ensure internal resources have the capacity to do the work, and assess the current infrastructure to make sure the integrations you want can be managed.

7.  Trading Needs Covered for the Full Lifecycle

A new system may not handle all your commodities – either current or planned. Some systems are not capable of handling carbon credits or renewables, or you may have some trades that use pricing models that are not standard to your system. For example, Power Purchase Agreements (PPAs) are complex contracts that include customized pricing formulas, long-term capacity profiles, and bespoke payment terms.

It’s important to know of the system’s capabilities upfront so you have a plan for managing the assets or instruments that are not covered in the new system. Ask yourself and your team the following:

• Can the system handle your requirements for confirmation, marking, settling, delivery, invoicing, payment?
• If you need custom data to enrich your trades, is this easy to set up and maintain?
• Is the valuation engine capable of handling specific items such as power block conversion that pertain to your business?

8.   Business Process Impact

For better or worse (hopefully for the better), new workflows impact how employees manage their daily tasks.

Make sure you know which business processes will change and how those changes will impact your team. You may face pushback from employees whose jobs will change significantly or who may fear the new, more efficient system will replace their jobs.

In some cases, you may be choosing to make small ease of use concessions in exchange for more robust audit and traceability — and employees need to be educated on why the extra work is good for the company as a whole.

Also, as mentioned above, implementations require work from internal resources, and busy employees will not be excited to add more work to their plates. Thankfully, there are several ways to help your team feel comfortable from Day One.

9.   Project Members

It is essential that you know who will be involved in the project and that you involve them in the entire process from the start. This will ensure their support, engagement, and assistance in the implementation, removing potential obstacles in advance.

• Project sponsors need to understand the value of the new system and will want routine updates throughout the implementation. Once the system is live, they will look for positive results.
• Team leads will provide hands-on input in choosing the new system and managing the implementation process to ensure the project stays on track. You need to make sure they have the capacity to do so and clear goals to report on.
• The system users need to understand how the new ETRM system will impact their daily jobs and what they need to do to prepare for it, including helping with the implementation. You need to be sure they have the capacity to be involved with the implementation and learn the new system while continuing to do their jobs.
• Everyone else the project impacts — from finance, accounting, trading, risk, compliance, IT, etc. — needs to be fully aware of the project and how it will impact them so there are no surprises. You do not want to begin a new accounting process, for example, without warning the accounting team in advance. They may also get excited about the new system and ask for integrations (as discussed above) and you will want to determine budget for such requests.

10.  Regulatory and Compliance Obligations

This is not optional. A new system may automate compliance checks or produce reports to help you adhere to reporting requirements such as Sarbanes-Oxley (SOX), Dodd-Frank, and EMIR. Make sure you know exactly how the new ETRM system will track and provide required data, to ensure you do not miss any obligations or deadlines and that your data is accurate and timely.

For example, SOX requirements on auditing user access should be considered when designing your user roles, permissions and groups, and setting up the administrators to be in charge of them.

The More You Know, the Better Your Implementation Will Be

Bottom line: don’t skimp on planning and preparing for your ETRM implementation. Take the time upfront to understand your goals, know how the system will achieve those goals, and collaborate with your team so everyone is prepared and working together.

If you create a clear and comprehensive plan and involve all stakeholders in the process, your team will be engaged and committed to the project’s success. At the same time, a careful evaluation of technical requirements and integration challenges — before you choose a new ETRM system — will help you avoid project delays and unexpected costs.