Solar Permits in Indiana: Duke Energy, AES Indiana & NIPSCO Requirements 2026

Indiana solar permits require a building permit and an electrical permit from your local Authority Having Jurisdiction (AHJ), plus a utility interconnection application submitted to Duke Energy Indiana, AES Indiana, NIPSCO, Indiana Michigan Power (I&M), CenterPoint Energy, or your serving rural electric cooperative before your system can export power. Residential permit fees typically range from $150 to $400, the AHJ approval window runs from a few days to several weeks, and utility Permission to Operate adds another 2 to 8 weeks.

Indiana enforces the 2017 National Electrical Code with state amendments for one- and two-family dwellings under the Indiana Residential Code. New solar customers of all five investor-owned utilities are enrolled in the Excess Distributed Generation (EDG) net billing program rather than full retail net metering, with excess generation credited at 1.25 times each utility’s avoided cost rate. Indiana has no state Renewable Portfolio Standard, but offers a property tax exemption on the added home value from solar, a sales tax exemption on qualifying equipment, and the NIPSCO Feed-In Tariff for eligible customers in northern Indiana.

This guide covers every major Indiana city, all five investor-owned utility territories, the applicable Indiana state codes, and how to submit a plan set that earns first-pass AHJ approval.

Indiana Solar Permit Quick-Reference: City-by-City Summary

Requirements vary substantially across Indiana cities. The table below summarizes the key variables for each jurisdiction covered in this guide.

City	AHJ	Utility	Permit Type	Review Timeline	Key Differentiator
Indianapolis	Dept. of Business & Neighborhood Services (DBNS)	AES Indiana	Building + electrical permits via Accela Citizen Access	~5–10 business days residential	Marion County uses unified DBNS portal; ICC IRC base
Fort Wayne	Allen County Building Dept.	Indiana Michigan Power (I&M)	Building + electrical permits	~2–4 weeks	Allen County PrimeGov portal; I&M serves NE Indiana
Carmel	City of Carmel Building & Code Services	AES Indiana (primary); Duke Energy IN (parts)	Building + electrical permits	~10–15 business days	Hamilton County; mixed utility territory; HOA pre-approval common
Fishers	City of Fishers Building Inspections	AES Indiana / Duke Energy IN (varies by address)	Building + electrical permits	~10–15 business days	ePermit Center online portal
South Bend	Monroe County Building Dept. unified with City of South Bend Bldg. Dept.	NIPSCO	Building + electrical permits; ground-mount needs Accessory/Foundation Permit first	Same-day to 2 weeks (rooftop)	Ground-mount permit sequencing rule; $60 minimum permit fee (2026)
Bloomington	Monroe County Building Dept. + City Planning & Transportation (zoning)	Duke Energy Indiana	Electrical permit ($50) + zoning review	Same-day rooftop / ~1 week ground-mount	Monroe County is the AHJ; Bloomington is SolSmart Gold
Evansville	Vanderburgh County Building Commission	CenterPoint Energy	Building + electrical permits	~2–4 weeks	CenterPoint EDG (was Vectren); first IOU to end net metering

Indiana Solar Permitting Framework: State Codes and Utility Oversight

Before diving into city-level requirements, it is essential to understand the statewide baseline that every Indiana AHJ operates within. Two regulatory layers govern Indiana solar installations: the Indiana Residential Code (IRC) and its adopted NEC edition, and the Indiana Utility Regulatory Commission (IURC) rules governing utility interconnection.

Indiana Residential Code and NEC Adoption

The Indiana Fire Prevention and Building Safety Commission enforces the 2020 Indiana Residential Code (IRC) for one- and two-family dwellings (Class 2 structures), which is based on the 2018 International Residential Code with state amendments. The electrical chapters of the IRC reference the 2017 National Electrical Code, making NEC 2017 the current statewide baseline for solar PV electrical work on residential rooftops. Indiana has not yet adopted the 2020 or 2023 NEC editions for residential structures, which makes Indiana’s residential electrical code older than that of most neighboring states. Plan sets prepared for Indiana AHJs should reference the 2017 NEC unless a specific local jurisdiction confirms it has adopted a newer edition by local amendment. The separate Indiana Electrical Code (675 IAC 17), which governs commercial and Class 1 structures, was last formally adopted in 2009 and is older still; an Indiana Department of Homeland Security rulemaking to update the Indiana Electrical Code to NEC 2023 was active through 2025, with effective date pending.

Key NEC 2017 sections most commonly reviewed by Indiana plan examiners include Article 690 for solar PV systems, NEC 690.12 for rapid shutdown (the original RSD requirement), NEC 705.12 for the 120% busbar rule on load-side interconnections, and NEC 690.31(G) for DC conduit labeling. For the full breakdown of NEC requirements that apply to Indiana plan sets, see the solar PV labeling requirements guide and the rapid shutdown compliance roadmap.

Commercial and Class 1 structures fall under the Indiana Building Code (CIBC), which references different ICC base codes. Structural calculations must comply with ASCE 7 wind and snow load criteria for the specific project location. Local AHJs may add requirements above the state baseline through local amendments, so confirming the adopted code edition with the specific building department before finalizing any plan set remains the safest practice.

Confirm the adopted code edition with your specific AHJ before finalizing any plan set. While Indiana’s statewide residential baseline is NEC 2017, individual cities may have adopted newer editions by local amendment.

IURC Interconnection Framework for Indiana Utilities

All Indiana investor-owned utilities,  Duke Energy Indiana, AES Indiana, NIPSCO, Indiana Michigan Power (I&M), and CenterPoint Energy,  must follow interconnection rules under 170 IAC 4-4.3, the IURC’s customer-generator interconnection standards. These rules establish a tiered application system based on system capacity. For a complete walkthrough of the interconnection process, see the solar interconnection agreement checklist and guide.

Level	Capacity	Application Type	Notes
Level 1	10 kW or less, inverter-based, UL 1741 certified	Expedited (simplified)	Covers most residential rooftop installations; fastest review path
Level 2	10 kW to 2 MW	Standard with engineering review	Additional engineering review period; most light commercial systems
Level 3	Greater than 2 MW	Full impact and facility study	Reserved for commercial and utility-scale projects

All grid-tied inverters must meet UL 1741 and IEEE 1547 requirements for anti-islanding and advanced inverter functions. Municipal electric utilities and rural electric membership cooperatives (REMCs) are not subject to IURC retail interconnection rules and set their own procedures, which often retain more favorable terms than the EDG framework that applies to investor-owned utility customers.

Indiana Excess Distributed Generation (EDG): How Net Billing Works in 2026

Indiana transitioned away from full retail net metering for new solar customers of investor-owned utilities under Senate Enrolled Act 309 (2017), with the transition completing across all five IOUs by 2022. New residential and small commercial solar customers of Duke Energy Indiana, AES Indiana, NIPSCO, I&M, and CenterPoint Energy are now enrolled in the Excess Distributed Generation (EDG) program under each utility’s IURC-approved tariff.

Under EDG, each utility credits exported electricity at its EDG rate, calculated as the average wholesale price of electricity from the prior calendar year multiplied by 1.25. This is significantly below the retail rate. The IURC also approved ‘instantaneous netting,’ meaning excess generation is measured continuously rather than monthly, every kilowatt-hour exported is credited at the EDG rate, while every kilowatt-hour imported is charged at the full retail rate. The Indiana Supreme Court upheld this framework in early 2023.

EDG Grandfathering for Existing Solar Customers

Customers who installed systems while net metering was still available retain full retail net metering for a defined window. Systems installed before the end of 2017 receive net metering through July 1, 2047. Systems installed between 2018 and the date their utility ended net metering enrollment receive net metering through July 1, 2032. Once those windows close, those customers also transition to EDG.

EDG Rates by Utility (2025–2026 Reference)

Each utility files an annual EDG rate update with the IURC. AES Indiana’s recent EDG rate has been approximately $0.039/kWh,  well below its retail rate of roughly $0.14/kWh. CenterPoint Energy’s EDG rate has run in the same range. Duke Energy Indiana, NIPSCO, and I&M each maintain their own filed rates. Because the EDG rate updates annually, contractors should pull each utility’s most recent compliance filing from IndianaDG or contact the utility directly before sizing any system.

Because EDG credits are below retail, system sizing in Indiana should target self-consumption rather than grid export. Pairing solar with battery storage is increasingly common in Indiana for this reason. See the solar battery permit guide for ESS plan set requirements.

REMC and Municipal Utility Net Metering

Indiana’s rural electric membership cooperatives and municipal utilities are not subject to SEA 309 and may continue offering net metering or alternative compensation programs at their own discretion. Customers served by REMCs or municipal utilities should contact their provider directly to confirm the current compensation structure before finalizing any system design. NIPSCO additionally operates a Feed-In Tariff (FIT) program in northern Indiana that pays $0.13–$0.17/kWh on total generation for eligible systems, functioning more like an SREC program than a net billing arrangement.

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Duke Energy Indiana Interconnection: Service Territory, Application Process, and EDG

Duke Energy Indiana serves much of central and southern Indiana, including Bloomington, Carmel, Fishers, Lafayette, Terre Haute, Columbus, and most of the area outside Marion County in central Indiana. Duke’s interconnection process is administered through its standard distributed generation application portal, with separate procedures for systems under 10 kW (Level 1) and larger installations.

Duke Energy Indiana Interconnection Application Steps

1. Design your system. Work with your solar installer to finalize layout, equipment selection, and string configuration. Include a single-line diagram before applying.
2. Submit the interconnection application through Duke Energy Indiana’s distributed generation portal at duke-energy.com. Include the site plan, single-line diagram, and equipment specifications. Diagrams must be sealed by an Indiana-licensed professional engineer for systems above Level 1 thresholds.
3. Pay the application fee per the IURC-approved tariff. Duke Energy Indiana’s fee schedule mirrors the standard IURC tiered structure.
4. Receive technical and safety review from Duke Energy Indiana’s distributed generation team.
5. Execute the interconnection agreement and Standard Contract Rider No. 50 (Parallel Operation for Qualifying Facility) or the applicable EDG rider.
6. Pass AHJ inspection and receive the bidirectional meter from Duke. Duke installs a new bidirectional meter at the customer’s existing meter base.
7. Receive permission to operate from Duke and begin exporting under the EDG rider.

Duke Energy Indiana EDG Rate

Duke Energy Indiana files its EDG rate annually with the IURC under Standard Contract Rider No. 50. The 2024 filing proposed an energy rate of approximately $0.0429/kWh and a capacity rate of $6.59/kW-month. Rates update annually based on the prior year’s wholesale energy market. Contractors should pull the current filed rate from the IURC docket or contact Duke Energy Indiana directly before sizing any system in Duke territory.

The Section 25D Residential Clean Energy Credit expired for expenditures made after December 31, 2025, under the One Big Beautiful Bill Act. See the solar tax credits 2026 guide for how this affects the financial case for new Indiana installations. Indiana’s state-level property and sales tax exemptions remain in effect.

For more on the financial case for solar in Duke Energy Indiana territory and how the EDG rate affects system sizing decisions, see the complete solar interconnection agreement guide and the solar tax credits 2026 guide.

AES Indiana Interconnection: Indianapolis Metro Service Territory

AES Indiana (formerly Indianapolis Power & Light, IPL) serves Indianapolis and most of Marion County, plus parts of surrounding counties. AES Indiana operates the most active distributed generation interconnection process in the state by volume, given the population density of its service territory.

AES Indiana Interconnection Application Process

AES Indiana administers interconnection through its online distributed generation portal at aesindiana.com. The application sequence mirrors the standard IURC framework: Level 1 expedited review for systems 10 kW and below, Level 2 standard review with engineering analysis for 10 kW to 2 MW, and Level 3 for systems above 2 MW. Application fees follow the IURC-approved schedule, with separate charges for the bidirectional meter upgrade where required.

AES Indiana’s recent EDG rate has been approximately $0.039/kWh, among the lowest in the state, which makes self-consumption sizing especially important for Indianapolis-area systems. The AES Indiana retail rate sits near $0.14/kWh, creating a roughly 3.5x gap between the value of consumed solar versus exported solar.

NIPSCO Interconnection: Northern Indiana

Northern Indiana Public Service Company (NIPSCO) serves the northern third of Indiana, including South Bend, Mishawaka, Gary, Hammond, Valparaiso, Crown Point, and surrounding communities. NIPSCO operates two relevant programs for solar customers: the standard EDG net billing program for new customers under SEA 309 and a Feed-In Tariff (FIT) program with a separate enrollment path.

NIPSCO Feed-In Tariff (FIT)

The NIPSCO FIT pays a fixed per-kWh rate on total generation rather than just excess generation. Recent NIPSCO FIT rates have been approximately $0.15–$0.17/kWh for systems between 5 and 10 kW and approximately $0.13–$0.15/kWh for systems above 10 kW. The FIT is contract-based and capacity-limited; enrollment is on a first-come basis until the program cap is reached, and rates are subject to change. Customers must choose between FIT enrollment and EDG enrollment; the two programs are mutually exclusive.

The NIPSCO FIT often produces better financial outcomes than EDG for systems sized to a customer’s actual consumption, because it pays on total generation rather than just exports. Confirm current FIT availability with NIPSCO directly before finalizing any system design in northern Indiana.

Indiana Michigan Power (I&M) Interconnection: Northeast Indiana

Indiana Michigan Power, an AEP subsidiary, serves Fort Wayne and most of northeast Indiana including Allen County, plus parts of southwest Michigan. I&M follows the IURC-approved interconnection process with the same level 1/2/3 tiered structure used by other Indiana IOUs. I&M’s EDG rate updates annually under its IURC-filed tariff.

I&M maintains a residential retail rate near $0.16/kWh, slightly above the state average, which improves the financial case for self-consumption sizing in northeast Indiana relative to AES Indiana or Duke territory.

CenterPoint Energy Interconnection: Southwest Indiana

CenterPoint Energy (formerly Vectren) serves Evansville and southwest Indiana. CenterPoint was the first Indiana IOU to end net metering enrollment for new customers, with the transition to EDG taking effect in 2021. CenterPoint’s EDG case was the one ultimately decided by the Indiana Supreme Court in early 2023, upholding instantaneous netting at the EDG rate. CenterPoint maintains the highest residential retail rate among Indiana IOUs at approximately $0.17/kWh, which partially offsets the unfavorable EDG framework for self-consumption sizing.

City-by-City Solar Permit Requirements in Indiana

Indianapolis Solar Permits

Solar installations in Indianapolis are permitted through the Marion County Department of Business and Neighborhood Services (DBNS). Both building and electrical permits are required, and applications are submitted through the Accela Citizen Access portal or in person at the City-County Building. The DBNS process applies countywide across Marion County, including Indianapolis proper and the included townships.

• Permit type: Building permit + electrical permit (typically issued together on solar applications)
• Submission: Accela Citizen Access portal at citizenaccess.indy.gov
• Utility: AES Indiana – submit interconnection through aesindiana.com
• Code: Indiana Residential Code (2018 IRC base) and NEC 2017 for residential structures
• Typical timeline: 5–10 business days for residential rooftop systems with complete documentation
• Contact: Indianapolis DBNS, 1200 Madison Avenue, Suite 100, Indianapolis, IN 46225 / (317) 327-8700 / permitquestions@indy.gov

Indianapolis DBNS reviews electrical and structural plans together. Submitting an incomplete electrical single-line diagram is the most common cause of revision requests. Include a label schedule referencing the specific NEC 2017 sections.

Fort Wayne Solar Permits

Solar installations in Fort Wayne fall under the Allen County Building Department, which administers permits for both unincorporated Allen County and the City of Fort Wayne under a consolidated department. Both building and electrical permits are required. Applications submit through the Allen County PrimeGov portal or in person.

• Permit type: Building permit + electrical permit
• AHJ: Allen County Building Department
• Utility: Indiana Michigan Power (I&M) – submit interconnection through indianamichiganpower.com
• Code: Indiana Residential Code with NEC 2017 for residential
• Typical timeline: 2–4 weeks for residential, longer for ground-mount or commercial

Carmel Solar Permits

Carmel handles solar permits through the City of Carmel Department of Community Services / Building & Code Services. Carmel is a Hamilton County community served by a mix of utilities – AES Indiana is the largest electric provider in the city, with Duke Energy Indiana also serving parts of the area. Confirm utility service territory by address before preparing the interconnection application. The Carmel permit process is generally well-documented with online application submission, but HOA pre-approval is more common in Carmel than in most other Indiana cities given the prevalence of restricted communities. Indiana Code §32-21-13 limits HOA authority to prohibit solar but allows reasonable size and placement restrictions.

• Permit type: Building permit + electrical permit through Carmel Building & Code Services
• Utility: AES Indiana (primary) or Duke Energy Indiana – verify by address
• HOA review: Frequently required before permit submission; verify deed restrictions early
• Typical timeline: 10–15 business days for complete residential applications

Fishers Solar Permits

Fishers, also in Hamilton County, administers solar permits through its ePermit Center online portal. Both building and electrical permits are required. Fishers’ application process is fully digital, which generally produces faster approval timelines than counties with paper-based intake. Like Carmel, Fishers is a mixed-utility area; AES Indiana and Duke Energy Indiana both serve portions of the city depending on address.

• Permit type: Building permit + electrical permit through Fishers ePermit Center
• Utility: AES Indiana or Duke Energy Indiana – verify by address
• Typical timeline: 10–15 business days for complete residential applications

South Bend Solar Permits

South Bend administers solar permits through the City of South Bend Building Department, which serves both city and county properties under a unified department. South Bend has a permit-sequencing rule worth flagging: for ground-mounted solar systems, an accessory/foundation permit must be issued before the solar electrical permit on both city and county properties. Rooftop systems do not have this sequencing requirement. South Bend follows the 2020 Indiana Residential Code with NEC 2017 for residential electrical work.

• Permit type: Building (or Accessory/Foundation for ground-mount) + electrical permits
• Utility: NIPSCO (Northern Indiana Public Service Company)
• Sequencing: Ground-mount systems require an accessory/foundation permit BEFORE a solar electrical permit
• Minimum permit fee: $60.00 (effective January 1, 2026)
• Address: City Service Center, 215 S. Dr. Martin Luther King, Jr. Blvd, Suite 100, South Bend, IN 46601 / (574) 235-9554 / building@southbendin.gov

South Bend’s ground-mount permit sequencing is unique in Indiana. Submitting an electrical permit application before the foundation permit is approved will cause the electrical application to be held.

Bloomington Solar Permits

Bloomington has been a SolSmart Gold-designated city since 2022, recognizing its work to reduce barriers to solar adoption. Solar permits in Bloomington are issued by the Monroe County Building Department, not the City of Bloomington, and the application path differs for rooftop versus ground-mount systems. Bloomington is in Duke Energy Indiana’s service territory.

For rooftop installations within Bloomington city limits, the Monroe County Building Department issues the electrical permit (typically same-day over the counter, $50 fee), and the City of Bloomington Planning & Transportation does not require a separate Certificate of Zoning Compliance. For ground-mount systems, the County Building Department processes the electrical permit, the Planning Department appends an Improvement Location Permit, and the City Planning & Transportation department then reviews the site plan for zoning compliance, a process that runs about one week.

• Permit type: Electrical permit through Monroe County Building Department ($50)
• AHJ: Monroe County Building Department, 501 N Morton St, Suite 220, Bloomington, IN 47404 / (812) 349-2580
• Utility: Duke Energy Indiana
• Typical timeline: Same-day over-the-counter for rooftop; ~1 week for ground-mount with zoning review
• Historic district: Properties in a Bloomington historic district require a Certificate of Appropriateness (no fee) from the Historic Preservation Commission

Evansville Solar Permits

Evansville and Vanderburgh County administer solar permits through the Vanderburgh County Building Commission, a consolidated city-county building authority. Both building and electrical permits are required. Evansville is in CenterPoint Energy’s service territory, which is the smallest of Indiana’s investor-owned utility territories by geography but the highest-priced by retail rate.

• Permit type: Building permit + electrical permit through the Vanderburgh County Building Commission
• Utility: CenterPoint Energy (formerly Vectren)
• Typical timeline: 2–4 weeks for residential applications

NEC 2017 Requirements for Indiana Solar Permit Plan Sets

Because Indiana enforces NEC 2017 for one- and two-family residential structures rather than the 2020 or 2023 editions used in many neighboring states, plan sets prepared for other Midwest jurisdictions cannot be reused for Indiana without revisiting the code references. The following NEC sections are most commonly reviewed by Indiana AHJ plan examiners:

NEC Section	Requirement	Indiana-Specific Note
Article 690	Solar PV systems — sizing, overcurrent protection, disconnects, rapid shutdown, grounding	Primary code article for all Indiana solar plan sets under NEC 2017
690.12	Rapid shutdown — array conductors must reduce to safe voltage within specified time after initiation	RSD required on rooftop residential systems; NEC 2017 version applies (pre-2020 timing rules)
690.53	DC voltage label at DC disconnect	Stays at 690.53 under NEC 2017 (moved to 690.7(D) only in NEC 2020/2023)
690.56(C)	Buildings with rapid shutdown placard — red background with white text required	NEC 2017 placard color rules apply; the NEC 2023 contrasting-text simplification does NOT apply in Indiana
705.12	Interconnection rules — 120% busbar rule for load-side connections	Critical for AHJ plan review; must reference busbar rating, not main breaker rating
690.31(G)	DC conduit and raceway labeling — WARNING: PHOTOVOLTAIC POWER SOURCE every 10 feet	Commonly missed at Indiana inspections
Article 706	Energy storage systems — required when battery storage is included	ESS adds documentation scope beyond PV-only plan sets and pairs commonly with EDG sizing strategy

For complete documentation of all required labels and their exact wording under NEC 2017, see the solar PV labeling requirements guide. For battery storage permit requirements, see the solar battery permit guide.

PE Stamp Requirements in Indiana

Indiana requires structural calculations for solar installations to be sealed by a professional engineer licensed in the State of Indiana. An out-of-state PE stamp is not valid for an Indiana project under the Indiana Professional Licensing Agency rules. PE stamp thresholds vary by jurisdiction: Indianapolis metro typically requires PE-stamped plans for residential systems exceeding 12–15 kW, while ground-mount systems uniformly require PE-stamped foundation calculations regardless of size. Commercial installations universally require PE certification across Indiana. For a state-by-state breakdown of PE stamp thresholds and costs, see the solar PE stamp requirements guide.

Indiana Investor-Owned Utility Comparison: Duke vs. AES vs. NIPSCO vs. I&M vs. CenterPoint

Factor	Duke Energy IN	AES Indiana	NIPSCO	I&M	CenterPoint
Service territory	Central & southern Indiana	Marion County / Indianapolis	Northern Indiana	Northeast Indiana / Fort Wayne	Southwest Indiana / Evansville
Approx. retail rate	~$0.13/kWh	~$0.14/kWh	~$0.18/kWh	~$0.16/kWh	~$0.17/kWh
EDG framework	EDG (instantaneous netting)	EDG (instantaneous netting)	EDG OR Feed-In Tariff	EDG (instantaneous netting)	EDG (first IOU to transition)
Approx. EDG rate (recent)	~$0.04/kWh	~$0.039/kWh	Per IURC filing	Per IURC filing	Per IURC filing
Special program	Rider 50 (parallel operation)	Largest interconnection volume in state	FIT pays $0.13–$0.17/kWh on total generation	AEP subsidiary; uniform AEP processes	Highest retail rate; first to end NM
Application portal	duke-energy.com DG portal	aesindiana.com DG portal	nipsco.com DG portal	indianamichiganpower.com	centerpointenergy.com

Rates above are approximate and update annually based on each utility’s IURC filings. Confirm current EDG and retail rates with the specific utility before finalizing any system sizing or financial projection.

Common Indiana Solar Permit Rejection Reasons

Indiana AHJ rejection patterns track closely with national patterns, with a few Indiana-specific triggers. For a broader national view of rejection causes and how to prevent them, see the solar permit requirements and rejection avoidance guide.

Rejection Reason	Indiana-Specific Context	How to Prevent
Wrong NEC edition cited	Indiana enforces NEC 2017 statewide for residential; plan sets citing NEC 2020 or 2023 will be flagged unless the local AHJ adopted a newer edition by amendment	Confirm the AHJ’s adopted edition by phone before finalizing the plan set; cite NEC 2017 sections for residential by default
Out-of-state PE stamp	Indiana requires structural calculations sealed by an Indiana-licensed PE; out-of-state stamps are invalid	Use a PE licensed in Indiana; engage a PE stamping service that maintains Indiana licensure
Missing utility selection on application	Indiana has five IOUs plus dozens of REMCs and municipals; the wrong utility identified in the interconnection application causes the application to be returned	Verify utility service territory by address before preparing the interconnection package; do not assume utility from city alone
South Bend ground-mount sequencing	Ground-mount systems in South Bend require Accessory/Foundation Permit BEFORE Solar Electrical Permit; reversed sequence causes the electrical permit to be held	Submit the Accessory/Foundation Permit first and confirm issuance before applying for the electrical permit
Incorrect 120% busbar rule calculation	Common rejection trigger at all Indiana AHJs; calculation must reference panel busbar rating, not main breaker rating	Document the busbar rating from the panel equipment datasheet explicitly; show the arithmetic clearly in the plan set
Missing rapid shutdown documentation	Indiana enforces the NEC 2017 RSD requirement, including the red-background buildings-with-rapid-shutdown placard. The simpler NEC 2023 contrasting-text rule does not apply.	Reference NEC 690.12 and 690.56(C) for residential RSD; specify red background with white text on the placard
Incomplete or expired equipment datasheets	Indiana plan reviewers check UL listing currency on modules, inverters, and disconnects	Use current manufacturer datasheets with active UL listings; never use draft or expired spec sheets
HOA documentation missing in Hamilton County applications	Carmel and Fishers reviewers may require HOA pre-approval letter for properties in restricted communities, even though state law limits HOA prohibition authority	Verify deed restrictions early; obtain HOA pre-approval letter before AHJ application in Hamilton County

How to Get First-Pass Approval on Indiana Solar Permits

The contractors who move through Indiana’s diverse AHJ landscape without revision cycles share a consistent set of practices:

• Verify the specific AHJ’s adopted code edition before starting the plan set. Indiana’s statewide baseline is NEC 2017 for residential, but local amendments do exist. Call the building department.
• Confirm which utility serves the property address and which interconnection portal applies (Duke Energy Indiana, AES Indiana, NIPSCO, I&M, CenterPoint, or a REMC/municipal). City alone is not enough – utility boundaries cross municipal lines.
• Use PE stamps from engineers licensed in Indiana for both structural and electrical plans. Out-of-state stamps are not accepted.
• In South Bend, confirm whether the system is rooftop or ground-mount before sequencing the permit applications. Ground-mount requires the accessory/foundation permit first.
• In Carmel and Fishers, confirm HOA status and obtain any required pre-approval letters before AHJ submission.
• For NIPSCO customers in northern Indiana, confirm whether the customer wants EDG or FIT enrollment before finalizing system size – the two programs have different optimal sizing strategies.
• Include a dedicated label schedule in every plan set documenting exact label wording, format, and NEC 2017 section reference, not a generic note stating ‘all labels per NEC 690.’
• Size systems for self-consumption rather than export. Across Indiana IOU territories, the EDG export rate runs roughly 25–30% of the retail import rate – every kWh consumed on-site is worth roughly 3–4x more than every kWh exported.
• For systems including battery storage, plan for the additional permit and labeling scope. A PV-only plan set will not cover the documentation an ESS requires.

Conclusion

Indiana solar permitting is shaped by two factors that distinguish it from most neighboring states: the older NEC 2017 baseline for residential structures and the EDG net billing framework that values exported solar at roughly a quarter of the retail rate. Both factors influence plan set design and system sizing in ways that are easy to miss for installers used to states with NEC 2023 and full retail net metering.

The contractors and designers who move through Indiana’s AHJ landscape without revision cycles share one operational habit: they confirm jurisdiction-specific requirements before starting the plan set. That means verifying the AHJ’s adopted code edition, confirming the utility service territory, and reviewing the specific city’s checklist or portal requirements every time, for every project. With the federal Section 25D Residential Clean Energy Credit having expired at the end of 2025, every other level of permit-pass-rate efficiency, system sizing for self-consumption, and EDG-vs.-FIT enrollment for NIPSCO customers matters more than it did a year ago.

Solar Permit Solutions produces PE-stamped, AHJ-ready plan sets for residential and commercial solar projects across all 50 states, including Indianapolis, Fort Wayne, Carmel, Fishers, South Bend, Bloomington, Evansville, and all other Indiana jurisdictions covered in this guide. Create a free account at solarpermitsolutions.com to get started, or explore the complete blog library for more technical guidance on solar permitting, NEC compliance, and interconnection requirements.

Frequently Asked Questions

Which utility serves my Indiana address — Duke, AES Indiana, NIPSCO, I&M, or CenterPoint?

Indiana’s investor-owned utility territories are Duke Energy Indiana (central and southern Indiana, including Bloomington); AES Indiana (Marion County/Indianapolis and parts of Hamilton County, including Carmel and Fishers); NIPSCO (northern Indiana, including South Bend, Mishawaka, Gary, and Hammond); Indiana Michigan Power/I&M (northeast Indiana, including Fort Wayne); and CenterPoint Energy (southwest Indiana, including Evansville). Hamilton County is a mixed territory between AES Indiana and Duke Energy Indiana. Many Hoosiers are also served by rural electric membership cooperatives (REMCs) or municipal utilities, which are not subject to SEA 309 and may still offer net metering. Confirm service territory by address before preparing any interconnection documentation.

How long does Indiana solar permitting take?

AHJ permit approval timelines in Indiana vary widely. Bloomington / Monroe County issues rooftop electrical permits same-day over the counter. South Bend issues rooftop permits within days. Indianapolis runs roughly 5–10 business days for residential rooftop systems with complete documentation. Hamilton County (Carmel, Fishers) runs 10–15 business days. Fort Wayne and Evansville run 2–4 weeks. Utility interconnection adds another 2–8 weeks. Total project timelines from design through Permission to Operate typically run 6 to 16 weeks.