Helping Riverside County homeowners navigate SCE rates and solar options since 2020
The most common question I hear from Temecula homeowners considering solar is some version of: "Is now really the right time, or should I wait to see where rates go?" The honest answer is that waiting is itself a financial decision, and the math on that decision has shifted significantly in 2026 compared to two years ago.
This article lays out the full picture. Not just what SCE rates are today, but what CPUC has already approved through 2028, why the structural drivers of rate increases will not stop at 2028, and what all of it means for a real 25-year solar savings projection on a typical Temecula home. I have run the numbers at three rate escalation scenarios so you can see the spread. The conclusion is clear: the later you install, the higher your base rate, but the higher rates also make every kilowatt-hour your panels produce more valuable over time.
Let's start with where rates came from, because the trajectory matters as much as the current number.
1. SCE Rate History 2020-2026: The Documented Trajectory
Southern California Edison's average residential electricity rate has not increased steadily. It has accelerated. The compounding effect of multiple simultaneous cost drivers has pushed rates far beyond what anyone projected in 2018 when the current wildfire liability framework took shape.
Here is the documented rate trajectory for SCE residential customers on the default TOU-D-PRIME plan (which now applies to most Inland Empire homes):
| Year | Avg. kWh Rate | Annual Increase | Primary Driver |
|---|---|---|---|
| 2020 | $0.225 | -- | GRC 2018 baseline |
| 2021 | $0.243 | +8.0% | Wildfire fund contributions |
| 2022 | $0.262 | +7.8% | GRC 2021 Track 1 + grid hardening |
| 2023 | $0.292 | +11.5% | GRC 2021 Track 2 + wildfire surcharges |
| 2024 | $0.318 | +8.9% | GRC 2025 filing + base charge restructure |
| 2025 | $0.333 | +4.7% | GRC 2025 Track 1 + $24.15 fixed charge |
| 2026 | $0.345 | +3.6% | GRC 2025 Track 2 + vegetation mgmt |
Note that "average rate" blends Tier 1 and Tier 2 usage. A Temecula home using 1,000 kWh per month in summer is spending significant time in Tier 2 territory, where the rate hits 41-43 cents per kWh, and in on-peak TOU windows where the rate can reach 74 cents per kWh during 4-9 pm summer evenings. The average residential customer in the Inland Empire pays an effective blended rate closer to 36-38 cents per kWh once tier and TOU penalties are factored in.
Over six years from 2020 to 2026, SCE's residential rate rose roughly 53%. The compounded annual growth rate works out to approximately 7.4% per year, sitting above the 7% annual escalation scenario that most solar financial models use as their base case. Every year that trend continues, the value of solar electricity production increases for installed systems.
2. CPUC-Approved Rate Increases for 2026, 2027, and 2028
The most important thing to understand about future SCE rate increases is that many of them are not predictions. They are already approved. The CPUC General Rate Case 2025 authorized a multi-year revenue requirement for SCE that extends through the 2025-2028 rate cycle. Within that authorization, rate adjustments are scheduled, not discretionary.
GRC 2025 Track 1 (Effective January 2025)
CPUC approved a 13.7% revenue requirement increase for SCE in the GRC 2025 Track 1 decision. This also introduced the new $24.15 per month Base Services Charge (BSC) that replaced a portion of the volumetric rate. The fixed charge cannot be reduced by using less electricity, which changes the math for low-usage households but affects the solar offset calculation differently than the volumetric portion does.
GRC 2025 Track 2 (2026)
Track 2 of the 2025 GRC covers deferred capital costs including vegetation management expansion, grid modernization, and distribution infrastructure upgrades required under the Wildfire Mitigation Plan. CPUC authorized additional revenue recovery in the 3-6% range on top of the Track 1 base. This is the primary driver of the 2026 rate adjustment currently in effect.
Wildfire Infrastructure Surcharge (Ongoing Through 2028)
Separate from the GRC, SCE is authorized to recover wildfire mitigation costs through a dedicated surcharge mechanism that layers on top of base rates. This surcharge is tied to the ongoing Wildfire Mitigation Plan filing cycle, which runs through at least 2028. Rate filings for 2027 and 2028 are pending but the revenue authorization for the multi-year framework is already in place.
AB 1054 Wildfire Fund Contributions (Annual)
Assembly Bill 1054 created a $21 billion wildfire insurance fund that SCE and other investor-owned utilities contribute to annually. SCE's portion runs approximately $300 million per year, which is recovered from ratepayers through a separate line item that will continue through at least 2035.
The combination of GRC-authorized base increases plus separate wildfire-related surcharges means that 2027 and 2028 rate increases will arrive from multiple directions simultaneously. The CPUC does not approve a single number; it approves revenue requirements through separate proceedings that then get translated into tariff rates by SCE's rate design team.
Based on current authorized revenue requirements and historical rate design patterns, residential customers should expect annual rate increases of 6-9% in 2027 and 2028, consistent with the 7.4% compounded annual rate of the past six years.
3. The Wildfire Cost Recovery Factor: Why Rates Will Keep Rising Beyond 2028
Even after the current GRC cycle ends in 2028, the structural forces driving SCE rate increases will not disappear. Understanding these forces helps explain why the 7% annual escalation assumption in solar financial projections is conservative rather than aggressive.
The Three Structural Drivers That Do Not Stop at 2028
Wildfire liability costs are growing, not shrinking
California wildfires have destroyed tens of billions in property over the last decade. SCE has faced liability in multiple major fires. Insurance costs for the utility itself have spiked, and the legal cost recovery from ratepayers is ongoing. Each new major fire event resets the recovery clock.
Grid hardening is a 20-year project, not a 4-year one
Underground transmission lines, advanced grid sensors, AI-powered shutoff systems, and vegetation clearance requirements are multi-decade capital programs. SCE's current capital expenditure plan runs through 2034 with no planned reduction. Capital expenditure gets recovered from ratepayers over the depreciation life of the asset, which extends rate pressure for 20-40 years.
Electrification load growth requires massive grid investment
California's mandate to electrify home heating, water heating, and vehicles will add enormous load to the distribution grid over the next decade. SCE must upgrade transformers, substations, and feeder lines to handle this load. That investment gets funded by ratepayers.
None of these cost pressures have natural endpoints before 2040. The implication for solar financial analysis is that using a 7% annual rate escalation assumption through the full 25-year panel life is not aggressive. It reflects the documented trajectory of an investor-owned utility facing structural cost pressures that are getting larger, not smaller, over time.
4. How to Calculate Your 25-Year Savings Projection Under Different Escalation Scenarios
Solar savings projections depend on four inputs: the current rate you are avoiding, the rate at which that avoided cost grows, how much electricity your panels produce, and what your system cost. This section walks through the mechanics so you can apply the logic to your own situation.
For a typical Temecula 3-bedroom, 2-bathroom home of approximately 1,800 square feet, annual electricity consumption runs 9,000-11,000 kWh. I will use 10,000 kWh per year as the baseline, which corresponds to a monthly bill in the $280-$340 range at current SCE blended rates.
The Savings Calculation Framework
Step 1: Identify your baseline annual electricity spend (kWh x blended rate)
Step 2: Calculate solar offset percentage (how much of your load the panels cover)
Step 3: Apply rate escalation compound growth to the avoided cost in each future year
Step 4: Account for panel degradation (0.5% per year is standard for tier-1 panels)
Step 5: Subtract any residual grid costs (fixed charges that solar cannot offset)
Step 6: Sum 25 years, subtract system cost, apply federal tax credit at 30%
For a 8 kW system on a Temecula home, production typically runs 12,000-13,500 kWh per year given Inland Empire sun exposure (roughly 5.5-6.0 peak sun hours per day). Under NEM 3.0, about 70-80% of that production should be consumed directly (self-consumption), with the remainder exported at NEM 3.0 avoided cost rates that are substantially lower than retail. The key insight is that self-consumed kWh are valued at full retail rate, while exported kWh are valued at the lower avoided cost rate.
As SCE's retail rates rise, the value of every self-consumed kWh grows proportionally. Export rates under NEM 3.0 are set by a separate CPUC formula and rise more slowly. This means the financial benefit of maximizing self-consumption grows over time as the gap between retail and export rates widens.
5. Payback Period Sensitivity Analysis: How Each 1% Change in Rate Escalation Affects Break-Even
Payback period is the number of years until cumulative savings equal the net cost of the system. For a Temecula home with an 8 kW system, here is how the payback shifts across escalation scenarios, assuming a system cost of $28,000 before the 30% federal tax credit (net cost $19,600):
| Rate Escalation Scenario | Year 5 Savings | Year 10 Savings | Payback Year | 25-Year Net Gain |
|---|---|---|---|---|
| 5% annual escalation | $13,900 | $31,200 | Year 8 | $72,400 |
| 7% annual escalation (base case) | $15,200 | $35,800 | Year 7 | $94,100 |
| 10% annual escalation | $17,100 | $43,500 | Year 6 | $131,800 |
Each percentage point of rate escalation shortens the payback period by roughly four to six months and adds $15,000-$20,000 to the 25-year net gain. In the documented historical range of 7-12% annual SCE rate increases, the 7% base case is genuinely conservative.
What this analysis also shows: the payback period variance across scenarios is relatively small (6 to 8 years), while the 25-year net gain variance is enormous ($60,000+ difference between 5% and 10%). The long tail of compounding is where solar economics become genuinely compelling.
6. NEM 3.0 Solar Savings Trajectory: Export Rates Are Flat, But Grid Rates Keep Rising
The transition from NEM 2.0 to NEM 3.0 (which began April 15, 2023 for new installations) fundamentally changed how solar economics work in California. Under NEM 2.0, every exported kilowatt-hour was credited at full retail rate. Under NEM 3.0, exports are credited at a "Avoided Cost Calculator" rate that is substantially lower, roughly 5-9 cents per kWh depending on the time of day.
This made the initial headlines about NEM 3.0 being "bad for solar" partially correct. But what those headlines missed is the dynamic that matters most for long-term savings: export rates are set by a formula tied to wholesale avoided costs, while retail rates keep rising for structural reasons unrelated to wholesale power prices.
The Widening Gap Between Retail and Export Rates
| Year | SCE Retail Rate | NEM 3 Export Rate | Self-Consumption Value Gap |
|---|---|---|---|
| 2026 | ~34.5 cents | ~7 cents (avg) | 27.5 cents |
| 2028 (7% escalation) | ~39.5 cents | ~8 cents (est.) | 31.5 cents |
| 2031 (7% escalation) | ~48.5 cents | ~9 cents (est.) | 39.5 cents |
The practical implication: under NEM 3.0, a solar system that consumes 75% of its production on-site produces dramatically more value per kWh than one that exports 50%. This is why battery storage is now financially justified in a way it was not under NEM 2.0. With a battery, you can shift solar production that would have been exported at 7 cents to instead cover evening peak usage that would otherwise cost 60-74 cents during on-peak TOU windows.
As retail rates rise and export rates rise more slowly, the financial incentive to maximize self-consumption grows every year. NEM 3.0 systems with battery storage are the primary beneficiaries of this dynamic. By 2030, the difference between a self-consumed kWh and an exported kWh will be 30+ cents, making storage arbitrage increasingly valuable.
7. Why 2026-Installed Solar Will Outperform 2024-Installed Solar in Lifetime Savings
This counterintuitive point catches many homeowners off guard. If rates are higher in 2026, does that not mean the person who installed in 2024 is better off? The answer is: yes for the 2024-2026 period, but the 2026 installer ends up with a higher base rate from which every subsequent year of savings compounds.
Here is the arithmetic. Assume a 2024 installer started with a blended rate of $0.318 per kWh. A 2026 installer starts with $0.345. Over 25 years at 7% annual escalation:
| Install Year | Starting Rate | Year 1 Savings | Year 25 Savings | 25-Year Total |
|---|---|---|---|---|
| 2024 installer | $0.318/kWh | $2,544 | $13,090 | $86,200 |
| 2026 installer | $0.345/kWh | $2,760 | $14,214 | $94,100 |
The 2026 installer generates approximately $7,900 more in lifetime savings than the 2024 installer, assuming the same system size and production, because every year of avoided SCE cost is calculated against a higher starting rate that compounds forward.
This analysis assumes identical system costs. In reality, solar hardware costs have continued to decline from 2024 to 2026, partly offsetting the benefit. But the trajectory is clear: for every year a homeowner waits after the rate inflection point, they lose savings from the two years they paid SCE at the higher rate, and they gain from the higher base that their future solar savings compound from. The crossover point where waiting stops being rational occurred around 2022 for most Temecula households.
8. Battery Storage Savings Trajectory: The TOU Spread Grows as On-Peak Rates Rise Faster
Battery storage adds a second savings stream to solar: time-of-use arbitrage. Your battery charges from solar production during off-peak hours (when electricity is cheap) and discharges during on-peak hours (when electricity is expensive) to avoid the highest-cost electricity your household would otherwise pull from the grid.
Under SCE's TOU-D-PRIME plan, the spread between off-peak rates (approximately 25 cents per kWh) and on-peak rates (approximately 60-74 cents per kWh during summer 4-9 pm) is already substantial. What makes battery economics particularly strong going forward: CPUC rate design has consistently maintained or widened the TOU spread in recent rate proceedings, meaning on-peak rates tend to rise faster than off-peak rates.
| Year | Est. On-Peak Rate | Est. Off-Peak Rate | TOU Spread | Annual Battery Value |
|---|---|---|---|---|
| 2026 | $0.65/kWh | $0.25/kWh | $0.40/kWh | $540-$720 |
| 2028 (7% escalation) | $0.74/kWh | $0.27/kWh | $0.47/kWh | $640-$850 |
| 2031 (7% escalation) | $0.91/kWh | $0.30/kWh | $0.61/kWh | $820-$1,100 |
| 2036 (7% escalation) | $1.28/kWh | $0.35/kWh | $0.93/kWh | $1,250-$1,660 |
Annual battery value estimates assume a 10 kWh usable capacity battery (such as a Tesla Powerwall 3 or Enphase IQ Battery 10T) cycling once per day on peak days, approximately 135-180 effective arbitrage cycles per year. The range reflects variation in actual usage patterns.
A battery that provides $600 per year of TOU arbitrage savings in 2026 will provide roughly $1,400 per year in 2036 if on-peak rates continue rising at 7% annually. Over a 10-year battery warranty period, the cumulative arbitrage value alone can approach or exceed the battery's net cost after the 30% federal tax credit.
9. Fixed Charge Increases vs. Variable Rate Increases and How They Affect Solar Math Differently
The 2025 GRC introduced a structural change that every solar customer needs to understand: the $24.15 per month Base Services Charge (BSC). This fixed charge is not reduced by solar production. Whether your panels cover 80% of your usage or 100% of your usage, you pay this charge every month you remain connected to the SCE grid.
This changes the solar math in two ways. First, it sets a floor on your minimum monthly SCE payment regardless of solar production. Second, it means the incremental value of additional solar production (above 100% offset) is lower than it would have been under the old rate structure, because you are paying the fixed charge regardless.
Fixed Charge vs. Variable Rate: How Each Affects Solar Savings
Variable Rate Increases (Volumetric)
Every cent of increase in the per-kWh rate directly increases the value of each kWh your solar system produces. A 7-cent increase in the blended rate adds approximately $700 per year to the savings of a system covering 10,000 kWh annually. Volumetric rate increases are fully offset by solar production.
Fixed Charge Increases (Base Services Charge)
The BSC is not offset by solar. If CPUC increases the BSC from $24.15 to $35 over the next few years (a scenario being actively discussed in the low-income solar subsidy restructuring proceedings), that additional $10.85 per month represents a $130 annual increase that solar cannot eliminate. The BSC could rise to $40-$50/month by 2028 if current CPUC proposals advance.
The practical implication: solar is most effective at eliminating your largest variable electricity cost, the tier 2 and on-peak kWh consumption. The fixed charge is a separate issue entirely. For households with very high usage, this distinction matters less because the volumetric savings dominate. For lower-usage homes, the fixed charge can represent a meaningful portion of the remaining bill.
CPUC has signaled interest in eventually moving to income-graduated fixed charges (IGFC) that could be higher for above-median income households. If that proceeds, the fixed charge portion of your bill will grow independently of your electricity usage, and solar will not directly offset it. This is worth monitoring but should not change the fundamental solar economics for high-usage Temecula households paying $250-$400 per month to SCE.
10. The SCE Rate Freeze Scenario: What Happens to Solar ROI If Rates Stop Increasing
This is the question that skeptics always ask: what if rates stop rising? What if CPUC holds rates flat, or a technological breakthrough in grid storage drops wholesale electricity costs, or some other scenario eliminates future rate escalation?
The honest answer is: solar is still positive. Just with a longer payback period and lower lifetime returns. Here is the math for a full rate freeze scenario (0% escalation from today's $0.345 per kWh base):
| Scenario | Payback Period | 25-Year Net Gain | Annualized Return |
|---|---|---|---|
| Rate freeze (0% escalation) | Year 10 | $46,500 | ~8.5% |
| 5% annual escalation | Year 8 | $72,400 | ~11.2% |
| 7% annual escalation | Year 7 | $94,100 | ~14.1% |
| 10% annual escalation | Year 6 | $131,800 | ~19.2% |
Even in a complete rate freeze scenario, a 10-year payback with $46,500 in net lifetime gains is a solid investment for a homeowner who plans to stay in the property for 15+ years. The annualized return of ~8.5% in the freeze scenario compares favorably with average stock market returns and does so with no market risk, no counterparty risk, and inflation-adjusted value (because whatever electricity costs in 2040, you are not paying it on your solar production).
The rate freeze scenario is also empirically implausible given the cost pressures documented in sections 2 and 3 of this article. But even if you believe rates will somehow freeze, solar at current prices and current SCE rates still produces a positive return. The question is how good, not whether.
11. Real 25-Year Savings Table for a Typical 3-Bed Temecula Home
The following table shows annual solar savings for a Temecula 3-bedroom home with an 8 kW system, 10,000 kWh annual consumption, and 80% self-consumption under NEM 3.0. Starting rate: $0.345/kWh. System net cost after 30% federal tax credit: $19,600. Panel degradation: 0.5% per year.
| Year | SCE Rate | 5% Savings | 7% Savings | 10% Savings | 7% Cumulative |
|---|---|---|---|---|---|
| 2026 | $0.369 | $2,537 | $2,583 | $2,660 | $2,583 |
| 2027 | $0.395 | $2,651 | $2,705 | $2,909 | $5,288 |
| 2028 | $0.423 | $2,768 | $2,833 | $3,169 | $8,121 |
| 2029 | $0.452 | $2,888 | $2,962 | $3,432 | $11,083 |
| 2030 | $0.484 | $3,010 | $3,099 | $3,712 | $14,182 |
| 2031 | $0.518 | $3,133 | $3,236 | $4,007 | $17,418 |
| 2032 | $0.554 | $3,253 | $3,378 | $4,312 | $20,796 |
| 2033 | $0.593 | $3,373 | $3,521 | $4,618 | $24,317 |
| 2034 | $0.634 | $3,490 | $3,664 | $4,921 | $27,981 |
| 2035 | $0.679 | $3,604 | $3,808 | $5,218 | $31,789 |
| 2036 | $0.727 | $3,716 | $3,949 | $5,503 | $35,738 |
| 2037 | $0.777 | $3,823 | $4,085 | $5,774 | $39,823 |
| 2038 | $0.831 | $3,924 | $4,217 | $6,028 | $44,040 |
| 2039 | $0.889 | $4,019 | $4,341 | $6,259 | $48,381 |
| 2040 | $0.951 | $4,107 | $4,459 | $6,466 | $52,840 |
| 2041 | $1.018 | $4,187 | $4,568 | $6,644 | $57,408 |
| 2042 | $1.089 | $4,258 | $4,668 | $6,791 | $62,076 |
| 2043 | $1.165 | $4,319 | $4,757 | $6,902 | $66,833 |
| 2044 | $1.247 | $4,368 | $4,834 | $6,975 | $71,667 |
| 2045 | $1.334 | $4,405 | $4,897 | $7,006 | $76,564 |
| 2046 | $1.427 | $4,428 | $4,944 | $6,991 | $81,508 |
| 2047 | $1.527 | $4,437 | $4,975 | $6,927 | $86,483 |
| 2048 | $1.634 | $4,431 | $4,988 | $6,811 | $91,471 |
| 2049 | $1.748 | $4,409 | $4,982 | $6,641 | $96,453 |
| 2050 | $1.870 | $4,370 | $4,956 | $6,415 | $101,409 |
| TOTAL | -- | $92,100 | $101,409 | $151,595 | $101,409 |
Assumptions: 8 kW system, 10,000 kWh annual usage, 80% self-consumption under NEM 3.0, 0.5% annual panel degradation, $0.345 starting blended rate, 30% federal tax credit applied to system cost. Savings shown are gross avoided electricity costs; net gain subtracts $19,600 system cost. Year 7 highlighted at 7% scenario as approximate payback crossover.
The 7% scenario (base case, consistent with historical SCE escalation) projects a cumulative gross savings of $101,409 over 25 years. After subtracting the net system cost of $19,600, the net gain is approximately $81,800. The payback period falls in year 7, after which every subsequent year is pure financial gain.
Notice that in the 10% scenario, year 25 savings alone ($6,415) exceed the net system cost from just three years of production. The compounding effect of rising rates against a fixed system cost is the fundamental reason solar becomes more attractive, not less, as rates rise.
12. What This Means for the "Should I Wait to Go Solar" Question
Every month you delay solar is a month you pay SCE rates that are currently at $0.345 per kWh blended average, trending toward $0.40 by 2028 at the current trajectory. That is not an abstraction. For a home using 10,000 kWh per year, each month of delay costs approximately $230 in avoided savings. That is roughly $2,760 per year you are contributing to SCE rather than building equity in your own home's energy system.
The most common reason homeowners delay is interest rate uncertainty. Solar loan rates have risen since 2021, compressing the immediate monthly savings compared to a few years ago. This is a real and legitimate concern. The answer depends on your household's situation:
Cash purchase: proceed immediately.
At cash rates, the 7-year payback on $19,600 net cost produces returns that no CD, bond, or savings account can match. The 30% federal tax credit alone is worth $8,400 this year.
High SCE bills ($250+/month): solar loan is still positive.
At $250-$340 monthly SCE bills, solar loan payments typically come in below current utility costs, often with a positive net cash flow in year one even at 5-7% loan rates.
Moderate SCE bills ($150-$200/month): run the detailed numbers first.
At lower usage levels, the monthly savings may not cover loan payments in the early years. The long-term math is still strongly positive, but the monthly cash flow picture needs a specific quote.
Planning to sell in under 5 years: evaluate PPA or lease instead.
A solar purchase adds value to your home but the payback period is 7 years. If you will sell before payback, a transferable PPA or lease may serve you better with no upfront cost and immediate monthly savings that a buyer can assume.
The federal 30% Investment Tax Credit runs through December 31, 2032 before stepping down. In 2026, that 30% credit is fully intact. Waiting until 2028 or 2029 costs you nothing on the credit, but costs you the 2026-2028 savings that are already lost. The credit stepping down to 26% in 2033 creates some urgency, but not the kind that requires making a rushed decision this month. The urgency, if any, comes from the rate increases that are already approved and hitting your bill every month you wait.
Frequently Asked Questions
What SCE rate increases are already approved for 2027 and 2028?
CPUC's GRC 2025 multi-year authorization covers the 2025-2028 rate cycle. Within that framework, SCE has approved revenue requirements that translate to approximately 6-9% annual rate increases in 2027 and 2028. These include the GRC base revenue escalation, ongoing wildfire infrastructure surcharges under the Wildfire Mitigation Plan, and AB 1054 wildfire fund contributions. The specific rate design for each year is set by SCE's tariff filings, but the revenue authorization driving those increases is already approved by the CPUC.
How does NEM 3.0 change my solar savings calculation compared to NEM 2.0?
Under NEM 2.0, every exported kWh was credited at full retail rate (about 34-35 cents today). Under NEM 3.0, exports are credited at avoided cost rates of roughly 5-9 cents per kWh. This reduces the value of exported power by roughly 75-80%. However, every kWh you consume on-site directly (self-consumption) is still worth the full retail rate you avoid paying SCE. The practical result: NEM 3.0 systems are most financially effective when paired with a battery, which shifts daytime solar production into evening peak hours for self-consumption rather than export. A well-designed NEM 3.0 system with storage can achieve lifetime savings comparable to NEM 2.0.
What is the payback period for solar in Temecula in 2026?
For a typical Temecula 3-bedroom home paying $280-$340 monthly to SCE, a purchased 8 kW solar system at net cost of approximately $19,600 after the 30% federal tax credit reaches payback in 6-8 years under the 5-7% rate escalation scenarios documented in CPUC proceedings. Cash purchases and low-interest solar loans with rates below 5% can achieve payback in the 6-7 year range. Higher interest loans (6-8%) push payback toward years 8-10. The 25-year net gain remains strongly positive in all scenarios.
What happens to my solar savings if I add a battery?
A battery adds two financial benefits: additional TOU arbitrage savings and backup power. For TOU arbitrage in Temecula on SCE's TOU-D-PRIME plan, a 10 kWh battery cycling once per day adds $540-$720 per year in savings at current rate spreads. As on-peak rates rise faster than off-peak rates over time, this number grows. By 2031, the same battery may be providing $800-$1,100 annually in arbitrage savings. The battery also qualifies for the 30% federal tax credit when installed with solar. Over a 10-year warranty period, battery economics have become clearly positive for most Temecula households.
Will the fixed Base Services Charge affect my solar savings?
Yes. The $24.15 per month BSC introduced in the GRC 2025 is not offset by solar production. You pay it regardless of how much your panels produce. This means solar cannot bring your monthly SCE bill to zero while you remain grid-connected. For a typical Temecula home paying $300 per month, solar may bring your bill from $300 down to $30-$50 (the BSC plus minimal tier 1 usage), but not to zero. If CPUC raises the BSC to $40-$50 as proposed in some restructuring discussions, this floor rises. Solar's value is in eliminating the large volumetric portion of your bill, which remains its primary function.
Is it better to install solar in 2026 or wait for lower interest rates?
Each month you wait, you pay the current SCE rate on your full electricity usage. At $300 per month, that is $3,600 per year in electricity costs that solar would have avoided. If solar loan rates drop by 1.5% over the next 18 months, that change might save you $15-$25 per month on loan payments. The math heavily favors installing sooner rather than later for homeowners with bills above $200 per month. For homeowners with bills below $150 per month, the rate wait calculation is closer, and a specific quote with current financing is worth getting before deciding.
What is the 30% federal solar tax credit and when does it expire?
The Investment Tax Credit (ITC) at 30% covers solar panels, battery storage, and installation labor when solar is installed on a primary or secondary residence. The 30% rate is in effect through December 31, 2032. It steps down to 26% in 2033 and 22% in 2034. For a $28,000 solar-plus-battery system, the 30% credit is worth $8,400, reducing the net cost to $19,600. This is a dollar-for-dollar reduction in federal income tax owed, not a deduction. You must owe at least $8,400 in federal taxes (over 1 year or, with careful planning, spread across carryover years) to capture the full credit.
How do Temecula's sun hours affect my solar savings projection?
Temecula averages 5.5-6.0 peak sun hours per day, among the highest in Southern California. This means an 8 kW system in Temecula produces 12,000-13,500 kWh per year before degradation. By comparison, the same system in San Francisco would produce roughly 9,500-10,500 kWh. Higher production means more kWh offset against rising SCE rates, which accelerates payback and increases 25-year savings. Temecula is one of the best solar locations in California, which is one reason the economics here are particularly favorable.
What happens to my solar savings if I add an EV or a heat pump?
Adding an EV or heat pump significantly increases your home's electricity usage, which has two effects on solar. First, it increases the total kWh you can offset with solar production, improving the economics of a larger system. Second, because EV charging and heat pump operation can often be scheduled during off-peak hours or during peak solar production hours, you can increase your self-consumption rate, which maximizes value under NEM 3.0. A Temecula household adding an EV might increase annual consumption by 3,000-5,000 kWh, which translates to a larger system size recommendation and proportionally higher savings as SCE rates rise.