Bottom Line First
Moving from two charge-discharge cycles to one profitable cycle a day does not kill a C&I storage project.
It changes how you have to calculate it.
A lot of people just divide the old annual revenue by two. That is wrong.
What matters is the real margin on the remaining cycle and whether the battery is now oversized for the load that still pays.
KRL Power’s C&I energy storage systems need to be sized against the site’s current settlement method and actual load curve, not against an outdated two-cycle assumption.
What Actually Changed in 2026
China’s revised Basic Rules for the Medium- and Long-Term Electricity Market took effect on 1 March 2026. For entities trading directly in the market, fixed time-of-use price levels and periods are no longer artificially prescribed.
Electricity is not the same price all day.
It means you have to use the prices you actually settle under, not a permanent peak-valley table from three years ago. For broader market context, review KRL Power’s C&I energy storage under electricity marketization.
Before you touch any spreadsheet, check these:
- Current retail or market contract
- Real charging-period cost
- Real high-price discharge windows
- 15- or 30-minute load data
- PV output in those same windows
- Demand or capacity charges
- Export limits
- Battery operating constraints
Do not reuse an old ROI model until these are updated.
Does One Cycle Mean Revenue Drops 50%?
No.
This is the most common mistake.
The two old cycles were rarely equal. One was usually stronger than the other. If the weaker one disappears, the revenue drop is often much less than half. If both were similar, then yes, it can be close to 50%.
Correct approach:
New annual value = value of every cycle that is still economically executable
Not:
Old annual value ÷ 2
Rebuild the model with current tariff data. Simply changing the cycle count is not enough. See also KRL’s C&I energy storage ROI calculation guide.
Use the Real Net Spread, Not the Headline Number
Peak price minus valley price overstates the return.
What you actually need is:
Net margin per discharged AC kWh
= avoided cost during discharge
− (charging cost ÷ round-trip efficiency)
− variable cycling cost
Quick example (illustrative only)
| Input | Value |
|---|---|
| Charging price | RMB 0.30/kWh |
| Avoided high-price electricity | RMB 1.00/kWh |
| Round-trip efficiency | 90% |
| Cycling / degradation allowance | RMB 0.05/kWh |
Charging cost for 1 kWh AC out:
0.30 ÷ 0.90 = RMB 0.333
Net margin:
1.00 − 0.333 − 0.05 = RMB 0.617/kWh
Headline spread looked like RMB 0.70. Real margin is lower once losses and cycling cost are included. Only use price components that actually move when the battery charges or discharges.
One-Cycle Sensitivity
Assumptions:
1 000 kWh usable AC discharge per cycle, 1 cycle/day, 330 days/year, 0.30 charging price, 90% efficiency, 0.05 cycling cost.
| High-price value | Net margin | Annual arbitrage |
|---|---|---|
| 0.70 | 0.317 | 104 500 |
| 0.90 | 0.517 | 170 500 |
| 1.10 | 0.717 | 236 500 |
| 1.30 | 0.917 | 302 500 |
One cycle per day tells you almost nothing by itself. The drivers are the captured spread, usable energy, operating days, cycling cost and installed CAPEX.
Six Numbers That Decide the Project
-
Actual charging price
Use what the battery will really pay. Do not default to the published valley rate. -
Actual discharge value
Use the cost the site can actually avoid. A theoretical peak price is useless if the factory has no load at that time. -
Profitable discharge energy
Lowest of: usable battery energy, site load in the profitable window, PCS power × available duration.
This is the fastest way to spot an oversized battery. -
Usable AC energy
Nominal kWh is not sellable AC energy. Account for SOC limits, reserve, conversion losses, auxiliaries, degradation and operating restrictions.
KRL publishes the KRL-B261L as 125 kW / 261 kWh and the KRL-B522L as 250 kW / 522 kWh. Those are nameplate figures. For ROI work they are not guaranteed AC discharge energy. -
Cycling cost
Do not run a second cycle just because the battery can. Incremental revenue must beat incremental operating and degradation cost. If a weak cycle barely covers losses, leave the battery idle. See also KRL’s industrial peak-shaving approach. -
Required return
Positive savings ≠ good investment. Define the hurdle first (4-year or 5-year payback, minimum IRR, cash yield, financing constraint), then see what the site can support.
Maximum Affordable CAPEX as a Quick Filter
Simple screen:
Maximum affordable CAPEX = Annual sustainable net cash flow × target payback years
Example: RMB 180 000 annual cash flow, 5-year target → RMB 900 000 ceiling.
If the installed cost is well above that number, something has to change: reduce energy, reduce power, improve dispatch, add verified peak-shaving, improve PV self-consumption, cut EPC cost, or stop.
This is only a screening tool. It does not replace full NPV/IRR work. For cost context see KRL’s commercial energy storage cost guide.
When the Battery Is Simply Too Big
Tariff reform can leave the old capacity oversized even if the project is still viable.
Example: remaining evening opportunity is 380 kWh, proposed usable energy is 700 kWh. The extra capacity sits idle, raises CAPEX, lowers utilisation and stretches payback.
Size to the profitable load window first. Add capacity only when it has another clear job — demand management, PV shifting, backup, generator optimisation or contracted grid services. For a wider procurement framework, use KRL Power’s commercial and industrial energy storage system selection guide.
| KRL Platform | AC Power | Nominal Energy | Better fit when |
|---|---|---|---|
| KRL-B261L | 125 kW | 261 kWh | Profitable window is smaller |
| KRL-B522L | 250 kW | 522 kWh | Site load can use the extra capacity |
Do not buy the larger cabinet just because it stores more energy.
One Strong Cycle Beats Two Weak Ones
| Cycle | Net margin |
|---|---|
| A | 0.18 RMB/kWh |
| B | 0.65 RMB/kWh |
Running both increases throughput. Cycle A may add almost nothing after degradation and operating cost. Better strategy is often: charge in the cheapest window, discharge in the highest-value window, stay idle the rest of the time.
That is why a proper C&I EMS matters more than a fixed two-cycle timer.
Can Peak Shaving Fill the Gap?
Sometimes.
Total annual value = arbitrage + verified demand-cost reduction + PV self-consumption + contracted DR + other bankable revenue − O&M.
Every stream has to be verified on its own. Keep three cases:
- Conservative — only contracted or directly measurable savings
- Base — highly probable operating value
- Upside — less certain VPP or market opportunities
Do not prop up a weak project by moving uncertain future revenue into the base case. For market context see KRL’s 2026 C&I outlook.
Do not automatically add a capacity payment either. The 2026 national mechanism applies to qualifying grid-side independent storage under defined conditions. A factory-owned behind-the-meter battery does not automatically qualify.
What the EMS Should Optimise Now
Old fixed schedule:
01:00 charge → 09:00 discharge → 12:00 charge → 18:00 discharge
New objective is different.
Inputs: price (current or forecast), load forecast, PV forecast, SOC, reserve, demand ceiling, import/export limits, cycling cost, production schedule.
Objective: maximise net economic value, not daily cycle count.
Five Red Flags in an Old ROI Model
| Red flag | Action |
|---|---|
| Still assumes 2 cycles × 365 days | Replace with executable cycles and real operating days |
| Nominal kWh treated as AC discharge | Recalculate usable AC energy |
| Headline tariff spread treated as profit | Deduct efficiency and cycling cost |
| Battery larger than profitable-period load | Re-size |
| ROI depends on uncertain future revenue | Move it to the upside case |
If any of these appear, recalculate before you buy.
GO / RE-SIZE / HOLD / STOP
| Result | Decision |
|---|---|
| Required return met with verified savings | GO |
| Economics close but battery oversized | RE-SIZE |
| Arbitrage weaker but verified peak-shaving or PV value remains | RE-OPTIMIZE |
| Return hangs on uncertain future revenue | HOLD |
| Remaining spread and load cannot support CAPEX | STOP |
Not every project should be saved. A serious supplier should be willing to tell a customer when less storage is the better decision.
What KRL Needs Before Recommending Anything
- Latest electricity bill
- Settlement contract
- 15-minute load curve
- PV capacity and production
- Transformer rating
- Grid import limit
- Backup requirement
- Export conditions
- Target payback or IRR
Only after these are checked should the project be matched to the KRL C&I portfolio. For demand-heavy sites also review the industrial peak-shaving guide. For cost-driven decisions use the commercial ESS cost guide together with the revised ROI model.
The goal is not to defend yesterday’s battery size.
It is to find the smallest configuration that reliably captures today’s bankable value.
Final Call
C&I storage can still work after TOU reform.
Two charges and two discharges are no longer a guaranteed business model.
Before you spend money, recalculate:
- Charging price
- Discharge-period value
- Net spread
- Profitable cycles
- Usable AC energy
- High-price-period load
- Cycling cost
- Verified peak-shaving value
- Annual net cash flow
- Maximum affordable CAPEX
One strong cycle that meets the required return → GO.
Battery too large → RE-SIZE.
Returns depend on unverified future income → HOLD.
Revised numbers cannot support the cost → STOP.
The best project after reform is not the one with the most capacity.
It is the one that turns the highest percentage of installed capacity into bankable cash flow.
FAQ
Is C&I storage still profitable after TOU reform?
Some projects are. It depends on the remaining net spread, usable energy, site load, cycling cost and CAPEX — not the number of daily cycles.
Does moving from two cycles to one cut revenue by 50%?
Not automatically. Recalculate each cycle on its own and drop only the value that is no longer executable.
What spread is needed?
There is no universal minimum spread. Use the real net-margin calculation—discharge-period avoided cost minus efficiency-adjusted charging cost and variable cycling cost—then test the resulting annual cash flow against CAPEX and the required return.
How should arbitrage profit be calculated?
Avoided cost during discharge minus efficiency-adjusted charging cost minus variable cycling cost. Do not use peak minus valley alone.
What data is required to recalculate ROI?
Use the latest settlement or retail contract, actual charging and discharge prices, 15-minute load data, PV profile, demand or capacity charges, export limits, battery operating constraints, transformer and grid-import limits, backup requirements, and the target payback or IRR.
Should the battery be smaller after the schedule change?
Sometimes. If the remaining profitable load window cannot use the original battery capacity, downsizing can reduce CAPEX, improve utilisation and shorten payback. Keep extra capacity only when it has another verified role.
Can nominal capacity be used directly in the model?
No. Apply SOC limits, reserves, losses, auxiliaries and degradation.
Can peak shaving replace lost arbitrage?
Sometimes. Peak shaving can help fill the gap when the site's billing creates a measurable demand-related cost and the battery can reliably reduce that billed peak. Only verified savings should enter the base case.
Should the EMS still force two cycles?
No. Run an extra cycle only when its incremental value exceeds the losses and cycling cost.
When should the project be stopped?
Stop or redesign the project when verified revenue cannot support the required return after correcting battery size, PCS power, dispatch assumptions and bankable secondary savings.
What is the biggest change after the 2026 TOU reform?
Projects on market-based pricing can no longer rely on permanently fixed peak and valley periods. ROI must use actual settlement prices and executable windows.
Does China’s 2026 storage capacity-price mechanism automatically apply to behind-the-meter C&I batteries?
No. The article’s policy section notes that the 2026 national mechanism applies to qualifying grid-side independent storage under defined conditions. A factory-owned behind-the-meter C&I battery does not automatically qualify, so capacity-related revenue should be included only after confirming the project’s actual eligibility and settlement mechanism.
Fastest way to judge a post-reform project?
Calculate the remaining net spread, multiply it by realistic usable AC energy and operating days, add only verified secondary savings, then compare annual net cash flow with the required investment return.
How do you recalculate C&I storage ROI after a TOU change?
Use actual charging price, discharge-period value, round-trip efficiency, usable AC energy, cycling cost, operating days, site load and installed CAPEX. Replace the old two-cycle assumption with the current executable schedule.
How should maximum affordable CAPEX be screened after TOU reform?
For a simple first-pass screen, multiply sustainable annual net cash flow by the target payback years. If installed cost is well above that ceiling, re-size, improve dispatch, add only verified value streams, reduce EPC cost or stop. This screening method does not replace full NPV or IRR analysis.
How should a buyer choose between KRL-B261L and KRL-B522L after TOU reform?
Match the system to the profitable load window, site power demand and required return. KRL-B261L is published at 125 kW / 261 kWh and fits smaller profitable windows, while KRL-B522L is published at 250 kW / 522 kWh for sites that can use the additional power and nominal energy. Final ROI must use project-specific usable AC energy, not nameplate kWh alone.