The question of how electricity is handled in a commercial lease sits at the center of nearly every occupancy cost analysis, yet it receives less structured attention than base rent or free rent concessions. Whether electricity flows through a landlord's master meter or runs directly to a tenant's dedicated panel shapes both the gross cost of occupancy and the risk each party carries over a multi-year term. Getting the modeling right — before heads of terms are signed — is one of the most consequential analytical steps in any leasing assignment.
Why the Electricity Structure Changes Everything
The gross rent a tenant pays is only meaningful when electricity is factored in correctly. A lease with a low face rent but electricity included at above-market rates can produce a higher effective cost than a competing space where the tenant meters and pays the utility directly.
Electricity costs in commercial buildings vary with building vintage, HVAC configuration, the tenant's own equipment load, and local utility tariff structures. A law firm running dense workstations in an older building with pneumatic HVAC will carry a meaningfully different power budget than a logistics operator in a modern warehouse with LED lighting throughout. The structure of the lease — included versus separately metered — determines who absorbs those differences and who benefits when consumption falls.
From a lease-economics perspective, included electricity creates a fixed or semi-fixed cost that the landlord prices into the rent structure, while separately metered electricity is a variable cost the tenant manages directly. Each arrangement has a distinct modeling approach, a distinct risk profile, and a distinct set of negotiating levers.
What "Electricity Included in Rent" Actually Means
When a lease states that electricity is included in rent, it rarely means unlimited consumption at no additional charge. Most gross and modified gross leases that include electricity cap the landlord's obligation at a stated rate per rentable square foot per year, or at the consumption level represented by a specific connected load per square foot. Tenants should read the clause carefully before assuming the gross rent is fully all-in.
Landlords price the electricity component of a gross rent by estimating average building consumption, dividing it across leasable area, and embedding that estimated cost into the face rate. That embedded cost may be derived from historical utility bills, an engineered energy audit, or simply a market convention in the submarket. When a tenant's actual consumption exceeds the threshold, the landlord typically charges the overage at the utility's tariff rate — turning a fixed cost into a partly variable one.
The modeling challenge for an included-electricity lease is reconstructing what the landlord has priced in. If the landlord discloses an electricity inclusion rate — say, a hypothetical two dollars per rentable square foot per year — the adviser can convert that to a watt-per-square-foot assumption and test whether the tenant's planned operation will stay within or exceed it. That test should be run against the tenant's actual equipment schedule, not against a generic benchmark.
Advisers comparing an included-electricity option against a separately metered option need to separate what the gross rent contains from what it costs. That separation makes the rent comparison honest and prevents an included-electricity lease from appearing artificially cheaper simply because its electricity cost is embedded and invisible. Caps on electricity escalation clauses, the right to audit the landlord's utility invoices, and clear language defining what constitutes "excess" consumption are all achievable in a well-negotiated lease.
What Separately Metered Electricity Looks Like in Practice
A separately metered lease removes the landlord from the electricity billing chain entirely. The tenant contracts directly with the utility, receives its own invoices, and pays based on actual consumption measured at a dedicated meter. This structure is standard in full-service industrial and many suburban office campuses, and it is increasingly common in urban office redevelopments where landlords have invested in building-level submetering infrastructure.
The modeling advantage of a separately metered arrangement is transparency. The tenant knows exactly what it is paying for electricity because the utility bill arrives on the tenant's desk rather than being folded into a rent reconciliation. That transparency also creates a planning discipline: the tenant's facilities team can monitor consumption, benchmark it against industry norms, and implement conservation measures that reduce the occupancy cost — an operational lever that does not exist when electricity is bundled into rent at a fixed inclusion rate.
The risk in a separately metered lease lies in the tariff exposure. Commercial utility rates are set by regulated utilities or competitive suppliers and change on the utility's rate case schedule, which is outside the tenant's control. A tenant that models electricity at today's rate across a ten-year lease term without escalation assumptions is understating future cost with near certainty. Advisers should build in a reasonable escalation range — labeled clearly as a hypothetical scenario — to test occupancy cost sensitivity against realistic rate trajectories.
Separately metered arrangements also require attention to demand charges. Many commercial utility tariffs have two components: a consumption charge measured in kilowatt-hours and a demand charge measured in kilowatts of peak draw. A tenant with high-intensity equipment that runs intermittently — data center pods, commercial kitchen equipment, imaging suites — can face demand charges that dwarf the consumption component. The model must address both the consumption and demand elements to reflect true operating cost.
Building the Electricity Cost Comparison Model
The core comparison model sits a floor below the gross-rent headline: it reconstructs total occupancy cost per rentable square foot per year for each option, with electricity handled on the basis that each lease actually uses. The method has three stages — isolating the electricity component, projecting it over the lease term, and discounting it to a common present value.
For included-electricity leases, isolating the component means either obtaining the landlord's disclosed electricity inclusion rate or estimating it from public utility rate data and reasonable watt-per-square-foot assumptions for the building type. For a hypothetical office floor of twenty thousand rentable square feet with an estimated three watts per usable square foot of connected load and a blended tariff of twelve cents per kilowatt-hour, an adviser can build a bottom-up annual electricity cost estimate and compare it against what the landlord has stated is included. That comparison reveals whether the tenant is subsidizing other tenants' consumption or benefiting from economies of scale.
For separately metered leases, the model uses actual or benchmarked consumption data converted to annual cost at the applicable tariff. The tenant's engineering team or a third-party energy consultant can typically provide a watts-per-square-foot estimate for the planned use. When that is not available, published energy benchmarking databases — such as those maintained by the U.S. Energy Information Administration's Commercial Buildings Energy Consumption Survey — provide use-type averages that can serve as reasonable placeholders, clearly labeled as estimates.
Projecting either cost stream over the lease term requires a growth rate assumption for electricity rates. Historically, commercial electricity rates in the United States have increased on average in the low single digits per year, but that average masks significant regional and cyclical variation. The model should run at least three scenarios — a flat rate, a moderate escalation, and an adverse scenario — so decision-makers can see the full range of occupancy cost outcomes before they commit.
Discounting the projected cost streams to net present value is the final step and the one that ties electricity modeling directly to lease net present value analysis. The same discount rate used for base rent cash flows — typically the tenant's weighted average cost of capital or a specified hurdle rate — should be applied to the electricity cost stream. This ensures the comparison is apples-to-apples across options with different payment structures.
Demand Charges and Peak Load Planning
Demand charges deserve their own section in any electricity modeling guide because they are poorly understood and frequently underestimated by occupiers and their advisers alike. A demand charge is calculated on the highest fifteen-minute or thirty-minute interval power draw recorded during a billing period, multiplied by a rate expressed in dollars per kilowatt. Because it is based on a single peak event rather than average consumption, it can produce a large charge from a brief operational anomaly.
For tenants with stable, predictable loads — a standard office operation — demand charges are relatively modest and not particularly volatile from month to month. For tenants with intermittent high-draw equipment, the demand charge can represent a significant portion of the total utility bill in peak months. Those tenants should run peak-shaving scenarios in the model: what does occupancy cost look like if operational scheduling keeps peak demand below a defined threshold?
Peak-shaving strategies include staggering equipment startup sequences, negotiating time-of-use rate structures with the utility, and in some cases, installing on-site battery storage that absorbs demand spikes. Each of these has an upfront cost that belongs in the total occupancy cost model if the tenant intends to pursue it. Advisers who model only the base electricity rate without modeling demand management often understate the operational complexity of separately metered arrangements.
When comparing an included-electricity lease against a separately metered option for a demand-intensive tenant, the included arrangement may carry hidden value that the rent comparison alone does not surface. If the landlord's master meter blends the tenant's demand spikes across the full building load, the per-tenant effective demand charge falls. Quantifying that blending benefit requires utility rate schedules and building load profiles, but the analytical effort is justified on larger transactions.
Escalation Clauses and Electricity Adjustment Mechanisms
Leases that include electricity rarely do so at a fixed cost for the entire term. Most include an electricity adjustment mechanism that allows the landlord to pass through increases in utility costs above a base year or base amount. The structure of that mechanism — and how the adjustment is calculated and invoiced — has a direct effect on modeled occupancy cost and risk allocation. Failing to run this test before lease execution can produce surprise true-up invoices in the first operating year.
A common mechanism is an electricity inclusion rate tied to a base year utility cost per square foot. If the building's electricity cost per square foot rises above the base year amount, the landlord invoices tenants for a proportionate share of the increase. This transfers future rate risk back to the tenant despite the lease appearing to be a gross structure. The model must reflect the probability-weighted path of those future adjustments, not just the static year-one all-in cost.
Some leases use an electricity factor that adjusts annually based on a utility tariff index published by the relevant jurisdiction's public utility commission. This creates more predictability than an audited building cost method but still requires the adviser to model the index's historical trajectory and project it forward. The source of the index — and whether it tracks the specific rate schedule the building sits on — should be verified before it is embedded in the model.
The negotiating leverage on escalation mechanisms is often underestimated. Tenants can cap annual electricity adjustment increases, negotiate a grace period before the first adjustment takes effect, or require that adjustments be supported by auditable utility invoices. Negotiating those protections within an included-electricity lease changes the shape of the projected cost curve and should be modeled as a separate scenario so the tenant can assign an economic value to each concession. Each of those provisions changes the modeled cost trajectory and must be reflected in the financial comparison.
Gross-Up Provisions and Their Effect on Electricity Modeling
Gross-up clauses appear in operating expense reconciliations and have a parallel application in electricity modeling that many practitioners overlook. When a building is not fully occupied, its common-area and shared-system electricity costs are spread across a smaller tenant base. A gross-up provision allows the landlord to calculate each tenant's electricity share as if the building were at a specified occupancy threshold — typically eighty or ninety-five percent — even when actual occupancy is lower.
For the tenant, gross-up clauses in electricity reconciliations can produce invoices that exceed actual building electricity costs during low-occupancy periods. The practical consequence is that the tenant effectively subsidizes the landlord's carrying cost for vacant space. Modeling this requires an assumption about building occupancy over the lease term: if the building is currently at sixty percent occupancy and the lease runs seven years, what occupancy trajectory is reasonable, and how does the gross-up clause change the tenant's effective electricity cost as occupancy rises and the gross-up benefit diminishes?
Advisers should also distinguish between controllable and uncontrollable electricity under a gross-up clause. HVAC electricity for the base building is typically non-controllable and subject to gross-up; plug load electricity in the tenant's own demised space is not. Leases that conflate these categories in a single gross-up provision create modeling ambiguity that should be resolved during negotiation, not discovered at the first operating expense reconciliation.
Running the Full Lease NPV with Electricity Modeled In
The question of Separately Metered vs Included Utilities: How to Model Electricity in a Lease ultimately resolves into a lease NPV calculation where electricity is treated as a first-class cost component, not an afterthought. The NPV model should carry base rent, free rent, tenant improvement allowances, parking, and all operating expense exposures including electricity, discounted on a consistent basis across every option in the comparison set.
Building that model correctly requires a clear decision about how to treat the electricity component in each option. For included options, the adviser strips the estimated electricity value out of the gross rent to establish a comparable net effective rent, then adds the electricity cost back as a separate line item modeled on the terms of the lease's adjustment mechanism.
For separately metered options, the electricity cost enters the model directly as a separate annual outflow, escalated per the tariff scenario and demand-adjusted for the tenant's operational profile. The sum of base rent and electricity cost in year one gives the initial gross occupancy cost per square foot. Projected over the full term and discounted, it produces an electricity-adjusted lease NPV that is directly comparable to the included-electricity NPV from the other option.
Transparent assumptions reduce the risk that the analysis is revisited after a lease is signed with different numbers than the client recalled. Running the lease NPV under included-electricity terms versus separately metered terms — with equal rigor applied to each — gives the client the information to make an informed decision based on its own risk tolerance and operational profile.
Practical Due Diligence Steps Before the Model Is Built
No electricity model is more reliable than the underlying data it rests on. Before building the comparison, advisers should collect the building's utility account history or request that the landlord provide electricity cost per square foot for the trailing three years. Landlords who are negotiating in good faith will typically share aggregate building utility data to support a tenant's due diligence process, even in a gross lease where the electricity cost is otherwise embedded.
For separately metered spaces, the adviser should verify the meter configuration before assuming the tenant has exclusive metering. Some buildings that market spaces as "separately metered" use submeters rather than utility-grade interval meters, and the billing method under a submeter arrangement — particularly who reads the meter, what rate schedule applies, and how disputes are resolved — differs meaningfully from a direct utility account. The lease should specify the billing methodology and the applicable rate.
Energy audits ordered during the due diligence period can produce consumption benchmarks that significantly improve the accuracy of the electricity model. A Level 1 ASHRAE energy audit — a walk-through assessment — provides a quick view of the space's major energy systems and their operating characteristics. For transactions above a certain size or term length, a Level 2 audit with measured data gives the adviser the consumption inputs needed to build a defensible bottom-up electricity cost model rather than relying on square-footage averages.
Reviewing any existing subtenants' electricity arrangements in the building provides additional data points, particularly for gross lease structures where the landlord's embedded electricity rate affects every tenant. If comparable tenants in the same building on similar terms have faced electricity adjustment invoices, that history reveals how the adjustment mechanism has operated in practice — a more reliable input than the landlord's pro forma.
Connecting Electricity Modeling to the Broader Lease Decision
Electricity modeling does not exist in isolation. It informs and is informed by other lease variables: the HVAC delivery system (central air handling versus dedicated package units affects who controls and pays for cooling), the lease structure (gross, modified gross, net), the building's energy performance rating, and the capital improvement obligations each party carries. An adviser who models electricity in isolation, without connecting it to these related variables, produces a partial analysis that may misrepresent total occupancy cost.
The building's energy performance certification — where one exists and is current — provides a useful proxy for overall energy efficiency but should not be used as a substitute for utility cost modeling. Certification scores reflect base building performance, not tenant load. A building that appears cheaper on rent but sits on an inefficient mechanical platform may cost more in total occupancy than a competing building with a higher face rent and modern HVAC infrastructure.
Communicating the Analysis to Stakeholders
A technically sound electricity model is only useful if the client's decision-makers understand what it shows. Presenting three scenarios — flat rate, moderate escalation, adverse escalation — alongside a simple year-by-year total occupancy cost table gives the client the information it needs without requiring it to audit the model's formulas. The goal is a clear visual that connects each assumption to an outcome, so stakeholders can engage with the analysis rather than simply accept it.
Risk framing matters as much as the numbers. For a tenant that is highly sensitive to operating cost variability — a retail operator, a co-working provider, a startup on a fixed budget — the included-electricity structure may be worth a modest rent premium simply because it transfers rate risk to the landlord and creates a more predictable fixed cost. For a tenant with capital and operational sophistication — a law firm, a financial institution, a large corporate occupier — separately metered electricity with a disciplined conservation program may produce lower total cost over a longer term despite higher early-year uncertainty.
The adviser's role is to quantify the value of that risk transfer explicitly, presenting the NPV comparison under each structure so the client can make an informed decision based on its own risk tolerance. That quantification is what separates a lease recommendation grounded in analysis from one grounded in preference.
Advisers who build this level of rigor into their process differentiate themselves on analytical quality. Clients who have been shown the full occupancy cost picture — with electricity modeled honestly and transparently — develop greater confidence in their advisers' recommendations and are more likely to return for the next transaction and the next portfolio review. That differentiation compounds over time and reinforces the value of doing this work consistently and correctly.
About Advantai
Advantai is a commercial real estate intelligence and operations platform operated by ADVANTAGE AI LLC, a Delaware limited liability company. It connects client relationships, property research, documents, and financial decisions in one workspace for commercial real estate teams — advisers and brokerage teams, occupier and facility teams, and portfolio teams. The platform covers CRM and origination, requirements and site selection, Property X-Ray (an interactive 3D building workspace that surfaces mechanical system data and floor plate configurations for spatial due diligence), financial modeling and comparison (a structured multi-option lease comparison environment where changing one assumption updates every scenario simultaneously), document intelligence (which extracts and indexes lease provisions — including electricity adjustment clauses, gross-up thresholds, and meter specifications — and links them directly to the financial model), transactions and diligence, client collaboration, and portfolio strategy with critical dates.
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