Solar System Expansion: When Can You Add More Capacity?

A solar system expansion is possible only when the added capacity has a documented load, a physically and electrically valid design, and an approved utility/program path. It is not simply “more panels.” Before changing anything, freeze the original as-built, equipment, permission to operate, tariff or REC treatment, ownership, warranties, monitoring, and production record. Then compare an exact design delta that shows what stays, what changes, and which approvals must be reopened.

The best path may use spare capacity in existing equipment, add a separately controlled array, replace an inverter, build a second independent system, use another roof or ground location, correct loads first, or defer. A battery can shift available energy and add resilience/control; it does not generate additional solar energy. No architecture is automatically best.

Teamsun’s system-upgrades page is a contextual intake route, not proof that Teamsun can expand a particular system. This research found no verified Teamsun expansion designs, model compatibility, pricing, utility outcomes, program preservation, commissioning records, or warranty results. Apply every evidence request below to Teamsun and any bidder. To start with documents rather than a panel count, send the original system and load records to Teamsun.

Direct answer: add solar capacity only after four gates pass: need, design, approval, and ownership. The corrected current and future load must justify it; the roof/ground and equipment must support an exact revised one-line; the serving utility, AHJ and program administrator must accept the change; and the original tariff, REC, warranty, finance, lease/PPA, monitoring and tax records must be reconciled in writing.

Freeze the original solar system before designing an expansion

An expansion should begin with a reproducible original-system data room. Without it, a bidder may design against a sales proposal instead of the system the utility and municipality actually approved. The original contract, permit set, utility approval, final equipment and field installation can all differ.

Collect these records before anyone moves a module, opens equipment, changes settings or files a new application:

Original-system record	Exact return required	Expansion decision it controls
Legal and ownership	property owner, utility customer, solar owner, lender/lessor/PPA provider, REC/program payee	who may authorize an alteration and who receives value
Final design	as-built site plan, one-line, module/string/branch map, equipment schedule	baseline for every physical and electrical delta
Utility	interconnection application, agreement, meter plan, export limit, permission to operate	original approved capacity and operating condition
Program/tariff	net-metering, RRES, SMART, SREC, RE Growth, REC aggregator or other documents	whether an addition is separate, changes compensation or needs a new meter
Equipment	exact module, racking, inverter/microinverter/optimizer, rapid-shutdown, meter/CT and gateway models	compatibility, capacity, listing and monitoring constraints
Site	roof plan/age/warranty, structural basis, fire-access plan, ground rights, shading and obstructions	usable area and alteration risk
Performance	monitoring export, production meter, utility bills, service history and outages	current health and a baseline for added production
Warranty/service	manufacturer registrations, workmanship, roof, monitoring and service agreements	alteration, new-work coverage and callback ownership
Closeout	permits, inspection, commissioning, serial list, photos and owner training	evidence that the installed system matches the records

The U.S. Department of Energy’s guide for buying a home with existing solar recommends collecting system age, roof age, ownership, warranty and historical production data. Those records remain useful even when the current owner installed the system: an expansion contractor needs to know which obligations and equipment survive.

Reconcile discrepancies in a baseline register. If the utility record says 7.6 kWac but the equipment, portal or field label differs, mark the approved and installed values separately. If the program payee is not the homeowner, do not assume the homeowner can change meters or REC treatment. If the original installer still owns monitoring administration, obtain the needed access without sharing passwords.

Prove the additional load instead of expanding from a monthly bill

Capacity should answer a documented energy-use problem. A high bill can result from more kWh, a rate or supplier change, fixed charges, demand, an equipment fault, a second meter, or a seasonal event. Reconstruct 12–24 months of bills and interval data before converting dollars into a proposed array.

Build three load cases:

1. Corrected current load: remove duplicate meters, billing errors and temporary/abnormal use; identify failed HVAC, resistance backup heat, pumps, pool equipment or other repairable loads.
2. Committed future load: include only dated, supported changes such as a purchased EV, contracted heat pump, planned addition with load calculation, or known occupancy/business change.
3. Optional sensitivity: keep possible EVs, electrification, tenants or equipment in a separate low/base/high scenario rather than treating all future ideas as certain.

Expansion load-justification worksheet

Input	Historical/current	Corrected	Committed future	Optional sensitivity	Evidence/date
Annual billed kWh	___	___	___	___	bills ___
Monthly/seasonal profile	___	___	___	___	interval/bills ___
Peak interval kW, if available	___	___	___	___	utility export ___
Electric heating/cooling	___	___	___	___	model/load study ___
EV charging	___	___	___	___	miles/charger schedule ___
Water heating/pool/pumps	___	___	___	___	equipment/duty ___
Existing PV annual production	___	health-adjusted ___	___	___	monitoring/meter ___
Existing export/curtailment	___	___	___	___	utility/meter ___
Remaining grid purchases	___	___	___	___	bill reconstruction ___

Do not simply subtract annual production from annual use and size the difference. Model the proposed module positions, shade, orientation, snow/loss inputs, inverter behavior and export limit. NREL’s current PVWatts V8 calculator provides a transparent screening model and warns that its predictions contain assumptions and do not capture site characteristics beyond the inputs. A detailed expansion should model the original and added arrays separately when their equipment or planes differ.

Efficiency or load correction can be the right first project when it removes waste, frees service capacity, or prevents paying for generation that is not needed. It does not have to eliminate the expansion. The decision should compare the corrected load plus expansion against an expansion sized to an unresolved fault.

Compare seven expansion paths on the same goal

“Can I add panels?” hides several architectures. Compare each path using the same corrected/future load, production method, tariff/program record, approval assumptions, remaining asset life and total scope.

Path	When it may fit	Evidence required	Main risk to expose
Use spare existing inverter/string/branch capacity	original equipment has documented, code-compliant capacity and compatible new components	exact module/electronics match, manufacturer design, revised one-line and approvals	apparent nameplate headroom may fail voltage/current/string/branch/export rules
Add modules plus new module electronics	roof area and branch/service capacity support a matched addition	module-microinverter/optimizer/racking/connector and branch design	“modular” does not mean unlimited or universally mixable
Build a second independent PV system	preserving the original equipment/monitoring/warranty or program requires separation	separate inverter/branches/metering/monitoring and utility/program treatment	two systems can still share service/export constraints and confuse ownership
Replace/repower inverter and electronics	original inverter or roof electronics constrain capacity or are near a service decision	retained/removed/added schedule, new DC/AC design, warranty and utility delta	an expansion becomes a larger alteration with roof, downtime and warranty scope
Use another roof, ground mount or carport	original roof is full, weak, shaded or near replacement	land/roof rights, structure/civil, trench, zoning, access and separate production	civil/electrical/approval scope can outweigh better solar access
Correct efficiency/load or use controls	avoidable load, peak behavior or export limit drives the request	measured before/after load and operational acceptance	control shifts load; it does not cure inadequate energy or equipment
Add battery or defer	goal is outage support/time shifting, or evidence/approval is incomplete	exact load/islanding/export design; dated deferral plan	storage does not create solar kWh and can add a separate interconnection amendment

Tesla’s current U.S. homeowner guidance illustrates why second-system architecture belongs in the comparison: Tesla says individual panels cannot be added to an installed Tesla solar design but a second system may be possible (Tesla system performance guidance). That is a Tesla business/design rule, not a universal rule for every manufacturer or installer.

Conversely, a microinverter system may permit a supported addition, but “one inverter per panel” does not settle AC branch limits, breaker/bus capacity, gateway/controller compatibility, grid profile, utility aggregate rating or warranty. Current Enphase IQ8 documentation publishes model- and branch-specific limits and particular IQ7/IQ8 coexistence conditions. The exact installed and new model set—not the word “microinverter”—controls.

Draw the original-versus-expanded one-line and design delta

Every bidder should return one baseline drawing, one proposed drawing and a delta schedule. A new proposal that redraws only the added modules makes it difficult to see aggregate AC capacity, export, rapid shutdown, meter and service consequences.

Original-to-expansion design-delta register

Field	Original approved/as-built	Proposed expanded	Delta and approval effect
Module model/count/exact kWdc	___	___	+___ modules / +___ kWdc
Roof/ground zones	___	___	added area/structure ___
Inverters or microinverters	___ / ___ kWac	___ / ___ kWac	+/replace ___
Optimizers/strings/branches	___	___	new/mixed/retired ___
DC:AC ratio and clipping	___	___	modeled effect ___
AC connection and breaker	___	___	changed/retained ___
Service/bus/backfeed calculation	___	___	revised value/method ___
Rapid shutdown/fire access	___	___	equipment/path/label delta ___
Export limit/power control	___ at ___	___ at ___	setting/device/approval ___
Revenue/production meters and CTs	___	___	add/reconfigure/retain ___
Gateway/monitoring accounts	___	___	combined/separate owner ___
Utility/program/permit revision	___	___	new/amended/separate ___

Use exact units. kWdc is module nameplate; kWac is inverter output; kWh is energy; a programmed export limit is another value at a defined measurement point. Do not call all four “system size.” Threshold rules may use AC, DC, export, customer class or another definition.

The delta must identify retained, removed and added equipment by model and quantity. For a string inverter, recalculate module Voc at the design minimum temperature, operating voltage/current, string length, input allocation, DC:AC ratio and conductor/protection scope. For optimizers, use the manufacturer’s current compatibility and string rules. SolarEdge’s July 2025 residential optimizer inter-compatibility note, for example, distinguishes S-, R- and P-series RMA/retrofit combinations and warns against treating mixed generations as universally interchangeable.

For microinverters, return exact units per branch, continuous AC current, branch conductor and breaker, combiner/gateway/controller model, grid profile and aggregate AC. For either architecture, show meter/CT orientation, export control and what monitoring sees. A design can be electrically viable while producing two incomplete apps unless data ownership is designed too.

Pass the roof, ground, structure, fire and service gates

Available-looking roof area is not approved array area. Measure exact module dimensions and setbacks against roof age, material, structural basis, rafters/trusses, attachments, drainage, snow/wind design, shade, vents/chimneys, fire access, service paths and the roof manufacturer’s alteration rules.

Physical gate	Required evidence	Stop/pause condition
Roof life and warranty	roofer/owner record, condition, written alteration effect	roof likely needs replacement before the added system’s planned life
Structure and attachment	field dimensions, structural basis, exact racking/attachment	load path, fastening or deck/framing condition unresolved
Layout and shade	surveyed module layout and time-step shade/model input	generic aerial blocks conflict with field obstacles/setbacks
Fire and electrical access	current AHJ/code plan, pathways, rapid-shutdown labels/equipment	added array blocks required access or leaves incomplete shutdown scope
Ground/carport alternative	ownership, survey, zoning, civil/structural, trench and access	easement, setback, drainage, foundation or interconnection route unknown
Service equipment	voltage/phase, main/bus ratings, connection method, existing DER/storage	aggregate backfeed/service design absent or equipment condition unacceptable

Rhode Island’s statewide solar permit application shows the level of detail authorities can request: system type, capacity, inverter information, interconnection location, storage charging/use, mounting design and structural information (Rhode Island solar permit rule). Local requirements and current adopted codes still control the actual project. Do not copy Rhode Island fields into a Connecticut or Massachusetts permit and call it approved.

If roof life is short, compare reroof-and-expand, another structure, ground/carport, or defer. If a second array needs trenching, include survey, Dig Safe, civil restoration, conductor/voltage-drop design and property rights. No universal roof-area or ground-mount premium belongs in this guide.

Treat export, service and interconnection as hard gates

Existing permission to operate covers an approved configuration. It is not blanket permission for more module DC, inverter AC, altered export control, a second inverter, storage, a new connection point or different protective equipment. Ask the serving utility to classify the exact delta in writing.

Utility amendment packet

1. Original application, agreement, meter plan and permission to operate.
2. Original and proposed one-lines with changes clouded or tabulated.
3. Old/new module, inverter and protection data sheets.
4. Exact original, added and aggregate kWdc/kWac; proposed export at the defined point.
5. Existing/proposed battery, generator, meter, CT and control modes.
6. Service/bus/connection calculation and equipment ratings.
7. Site plan, equipment location and rapid-shutdown/labeling delta.
8. Correct customer, account, meter, owner, applicant, program and REC/payee roles.
9. Requested classification: amendment, add-on, second system, new application or other.
10. Study, meter, system-modification, inspection, witness-test and final-authorization milestones.

Do not enter zero for a utility-controlled study, transformer, meter or system-modification cost before the utility responds. Use an allowance or decision hold point. Likewise, do not promise a schedule the utility or municipality controls.

An export cap can make a larger array technically possible, but it changes the production/value model. Record whether the limit is inverter nameplate, certified power control, site aggregate or another measurement, how it fails safely, what monitoring records and whether program rules allow the configuration. “Non-export” is an operating design, not permission to omit interconnection.

Route Connecticut, Massachusetts and Rhode Island separately

The expansion decision changes sharply by the original program. Research was frozen August 10, 2026; retrieve the current tariff and written project direction again before contracting.

State	Current expansion evidence	What must be frozen before design approval
Connecticut	RRES Manual Version 2026.1, Appendix H defines an Add-On System at a site with existing PV as electrically separate, with a separate interconnection/RRES application and unique production meter; Eversource and UI dates/conditions differ	original net-metering/RRES status, Buy-All/Netting path, credit bank, existing/add-on production meters, REC ownership/payments, aggregate AC and separate application
Massachusetts	DPU requires the serving-utility interconnection route; DOER says legacy SREC/SREC II systems may not add panels/increase capacity within the qualified system, and an expansion must be separately metered and share no equipment if pursuing another eligible route	original SREC/SMART/net-metering qualification, Asset ID/aggregator, separate-equipment/meter design, serving utility, current SMART/RPS eligibility and credit consequences
Rhode Island	Current Net Metering and RE Growth rules use different sizing, metering, payment and REC structures; 2026 RI Energy/PUC materials specifically address original and second solar projects	original Net Metering or RE Growth tariff, meter arrangement, tariff term, exact added kWdc/kWac, three-year load basis where applicable, second-project/combined treatment and written RI Energy direction

Connecticut: do not miss the separate add-on design

The current RRES Program Manual, effective January 1, 2026, says the Add-On System must be electrically separate from the existing system and needs a separate application for interconnection and RRES approval. For the Netting incentive, it is behind the existing revenue meter but uses a unique production meter. The manual also describes what happens to a legacy net-metering credit bank and how REC payments for old and new systems are treated. Do not summarize that as “same net metering.”

Use the correct utility route: Eversource’s Connecticut application-to-connect page or UI’s RRES interconnection page. The installer/authorized agent, system owner and customer of record must be reconciled. Neither route proves the project will pass or preserve an expected payment.

Massachusetts: protect the original program record

Massachusetts DOER’s current Solar Carve-out guidance says capacity increases and panel additions are not allowed within an SREC-qualified system; an expansion considering RPS Class I or SMART must be separately metered and cannot share equipment with the original SREC system, subject to eligibility. That can favor a truly independent second system over using “spare” old inverter capacity.

The DPU utility interconnection hub routes projects through Eversource, National Grid or Unitil tariffs and requires written approval. Massachusetts’ current net-metering guide warns that expanding a facility can change the value of net-metering credits. SMART 3.0, SREC, net metering and interconnection are separate ledgers; passing one does not pass the others.

Rhode Island: resolve the tariff and meter before assuming expansion

Rhode Island OER’s current net-metering overview says eligible customer-sited systems are sized from the property’s three-year average consumption and describes different treatment above 100% consumption. Rhode Island Energy’s 2026 RE Growth page publishes current tariffs, program-year rules and interconnection enrollment.

In January 2026 regulatory responses, RI Energy defined an expansion for reporting as added kWac (new inverters/panels) or added kWdc (new panels) and discussed second-project/combined-meter treatment (RI PUC docket response). A docket response is not a substitute for the effective tariff and project approval. Freeze the current Rhode Island Energy tariff directory, exact original enrollment and written utility answer.

Reconcile ownership, program, warranties, monitoring and tax records

An owner may physically have roof space but lack unilateral contract authority to alter the system. A lease, PPA, secured loan, UCC filing, REC assignment, program certificate, roof warranty, condominium approval or original workmanship warranty can require notice, consent, separate equipment or an approved provider.

Original-and-expansion obligation ledger

Obligation	Original system	Expansion	Conflict/question	Written owner/date
Equipment owner / contract counterparty	___	___	consent/transfer ___	___
Utility customer / interconnecting customer	___	___	same or separate ___	___
Program and tariff term	___	___	meter/rate/term effect ___	___
REC/environmental-attribute owner	___	___	separate production proof ___	___
Loan/lease/PPA/security interest	___	___	alteration/payoff/insurance ___	___
Module/inverter/racking warranties	___	___	compatibility/authorized work ___	___
Workmanship and roof coverage	___	___	old/new boundary ___	___
Monitoring administrator and data	___	___	combined/separate/history ___	___
Federal/state tax records	adviser-controlled ___	adviser-controlled ___	basis/allocation/carryforward ___	___

Read the exact manufacturer warranties before mixing equipment or moving modules. Do not claim an alteration automatically voids coverage; do not promise it preserves coverage either. Ask each provider to identify the clause, covered serials, registration, authorized-work requirement, remedy and labor/access exclusions.

For a homeowner’s new expansion property placed in service in 2026, the current IRS page says the §25D Residential Clean Energy Credit is unavailable after December 31, 2025, so use $0 for that new-2026 input (IRS Residential Clean Energy Credit). Earlier eligible costs or unused carryforwards are separate tax facts; the IRS timing FAQ addresses carryforwards. A qualified tax adviser must determine the original and new basis, allocations, business use, carryforward, depreciation/recapture or other treatment. This page provides no personalized tax result.

Normalize the expansion price and commissioning acceptance

No audited Teamsun expansion price, labor range, model set or utility outcome was available. Compare quotes with one blank scope—not a generic price per added watt. Small additions can carry design, mobilization, permit, monitoring and interconnection work that do not scale linearly.

Expansion cost scope	Bid A	Bid B	Evidence/allowance
Diagnostic/data-room/as-built reconstruction	$___	$___	records/site visits ___
Added modules/electronics/racking	$___	$___	exact models/quantities ___
Retained-system changes/repower	$___	$___	retained/removed/added ___
Roof/structure/civil/trench/carport	$___	$___	fixed vs allowance ___
Service/panel/bus/backfeed/export control	$___	$___	calculation/equipment ___
Permit/fire/electrical/inspection	$___	$___	fees/owner ___
Utility study/meter/system modification	$___	$___	unknown/allowance/off-ramp ___
Program/REC/aggregator administration	$___	$___	responsibility ___
Monitoring/gateway/data plan/migration	$___	$___	combined/separate ___
Commissioning and acceptance tests	$___	$___	written protocol ___
Gross cash total	$___	$___	tax/program not subtracted
Finance principal/APR/fees/total payments	$___ / ___ / $___ / $___	$___ / ___ / $___ / $___	separate disclosure

Commission both the new capacity and its interaction with the old system. Closeout should include:

1. final as-built one-line, site plan and retained/removed/added equipment schedule;
2. exact old/new/aggregate kWdc, kWac and export setting at the defined point;
3. serial/model map, string or branch calculations, pairing/discovery and grid profile;
4. rapid-shutdown, labeling, protective-device and required functional tests;
5. meter/CT direction, production, import/export and power-control verification;
6. original and expansion monitoring access, timestamps, history and alert ownership;
7. original-system health baseline and a weather/irradiance-labeled new-production baseline;
8. permit/inspection, utility/program/meter and permission-to-operate records;
9. warranty registrations, workmanship boundary, roof closeout and service contacts;
10. owner training, excluded loads/functions and unresolved punch-list owner/date.

“Both apps are green” is not acceptance. The aggregate site readings, utility meter, export limit, monitoring, production meters and tariff/program records must agree.

Use a stop, pause or proceed gate

Proceed when corrected/committed load justifies the addition; the original data room is complete; the exact design delta passes roof/ground, structure, equipment, service, rapid-shutdown and export checks; the utility/AHJ/program path is written; ownership and warranties are reconciled; and price and acceptance are complete.

Pause when expansion seems feasible but bills/interval data, original one-line/PTO, equipment labels, roof life, branch/string capacity, utility classification, tariff/REC effect, monitoring administration, lender/lessor consent or tax allocation is missing. Make each a preconstruction condition.

Stop on the current proposal when it:

• sizes panels from a monthly dollar bill without rebuilding kWh/load;
• calls microinverters or optimizer systems “infinitely expandable”;
• uses apparent inverter nameplate headroom without string/branch/module calculations;
• adds capacity under an old PTO without a written utility route;
• assumes battery kWh replaces added solar energy;
• merges an SREC/SMART/RRES/RE Growth or net-metered system without program evidence;
• treats a second system as electrically/contractually independent while sharing undocumented service, meter, export or monitoring;
• subtracts a new-2026 homeowner §25D credit instead of $0;
• assigns no one to protect the original roof/workmanship/equipment warranties; or
• hides utility, service, roof, civil, monitoring or commissioning work in “TBD.”

If the packet is complete enough to test these gates, request an existing-system expansion review. The defensible deliverable is an original-versus-expanded evidence package and approval route, not a promise to fit a few more panels.

Frequently asked questions about solar system expansion

Can I add more panels to my existing solar system?

Possibly. Confirm corrected/future load, exact roof or ground space, module/electronics compatibility, string or branch capacity, service/bus/backfeed, export and rapid shutdown, utility/program amendment, ownership, warranties, monitoring and complete cost. A brand or inverter type alone cannot answer.

How many panels can I add to my inverter?

There is no safe universal count. Use the exact inverter, modules and string architecture; design-temperature voltage, current, input allocation, DC:AC ratio, clipping, manufacturer limits, export setting and utility approval. Whole-module increments then determine added Wdc.

Are microinverter systems easier to expand?

They can be modular, but expansion still depends on exact new/old models, AC branch limits, combiner/gateway/controller, grid profile, aggregate service/backfeed, utility application, monitoring and warranty. Do not translate “one per panel” into unlimited capacity.

Can I mix old and new solar panels?

Potentially, but electrical characteristics, connectors, physical size, racking, warranty and the inverter/optimizer/microinverter design must support the exact combination. Separate strings or branches may be necessary. Require manufacturer/design evidence rather than a visual match.

Will an expansion change my net metering or incentive?

It can. Connecticut has a specific separate Add-On System route; Massachusetts legacy SREC expansions can require separate equipment/metering; Rhode Island Net Metering and RE Growth have different meter and tariff consequences. Obtain written project-specific program and utility treatment.

Can I add a second independent solar system?

Possibly. It may preserve clearer equipment and warranty boundaries, but it still shares a property and often a service, customer load or export point. Define separate equipment, meters, monitoring, tariff/program, utility approval and service limits in the one-line.

Should I replace the inverter while expanding?

Only after comparing retained spare capacity, a second system and repower. An inverter change can solve capacity or compatibility limits, but it can also add optimizer/string, monitoring, warranty, permit, utility and downtime scope. Use a retained/removed/added schedule.

Will a battery solve the need for more solar?

Not if the problem is insufficient annual generation. A battery stores available solar or grid energy and changes timing, export or backup behavior. It cannot create additional kWh. Compare storage separately when resilience or time shifting is the actual goal.

Do I need another interconnection application?

Often an amendment, add-on, separate application or new application is required, but the exact route is utility/program specific. Existing PTO is not blanket permission. Submit the original and proposed one-lines, ratings, equipment, export and meter changes for written classification.

Does expansion require another permit?

Expect the AHJ to classify the added structural and electrical work under current local rules. Submit the revised layout, structure/attachments, one-line, equipment, service calculation, rapid-shutdown/fire access and labels. Utility approval does not replace municipal inspection.

Can I claim a federal residential credit for a 2026 expansion?

For new residential clean-energy property placed in service after December 31, 2025, current IRS guidance makes the §25D input $0. Earlier eligible facts or carryforwards are separate and require tax advice. Do not blend old and new costs or basis without an adviser.

What if my original solar installer is gone?

Reconstruct the data room from homeowner, utility, AHJ, manufacturer, lender/lessor, monitoring and program records. Verify the new contractor’s supported equipment and account access. Installer closure does not erase the original PTO, contracts, program or warranty terms.

Research method and intent boundary

Research was frozen August 10, 2026 using current IRS, DOE, NREL, CT PURA/Eversource/UI, Massachusetts DPU/DOER, Rhode Island OER/PUC/RI Energy, manufacturer and representative first-page sources. Official utility/program records control the local claims. Manufacturer materials show why exact architecture matters; they do not establish Teamsun product support or a universal design.

Representative 2026 SERP pages often present expansions as an inverter-headroom or price-per-watt exercise. Current homeowner threads ask whether mixed panels, microinverters, another installer, warranties, future EV/heat-pump load and a second system will work. Those sources informed the decision branches; no forum or competitor price, compatibility, tax, program, safety or outcome claim was adopted.

B162 owns the existing-system capacity expansion decision: original data room, load justification, design delta, physical/electrical/export gates, CT/MA/RI amendment, ownership/program ledger, cost scope and commissioning. New-system size/cost pages own pricing a fresh 5–15 kW design; the SolarEdge inverter replacement guide owns a failed-inverter route; and battery retrofit guidance owns storage additions. No Teamsun expansion capability, design, equipment, price, savings, schedule, warranty or approval is implied.