How to Prepare a Solar DPR for MNRE: Template and Checklist

A Detailed Project Report (DPR) for MNRE submission is the single most consequential document an Indian solar developer prepares. It determines whether a project receives scheme approval, subsidy disbursement, and connectivity priority, or gets returned for corrections that cost 3-6 months.

Most DPRs submitted by mid-market EPCs are returned not because the project is unviable, but because the document does not follow the MNRE’s prescribed format, misses mandatory sections, or uses data from unacceptable sources. This tutorial covers the complete DPR template, section by section, with the specific data requirements and common failure modes for each section.

Quick answer. An MNRE-compliant solar DPR must contain: (1) project overview and promoter details, (2) site feasibility study with GPS coordinates and land status, (3) solar resource assessment using MNRE-accepted data sources, (4) technical design section including PVsyst simulation with P50/P90 yield, equipment BOQ with BIS/ALMM compliance evidence, SLD, and structural assessment, (5) financial analysis with IRR, DSCR, and tariff calculations, (6) grid connectivity plan with STU/DISCOM approval letters, (7) environmental clearance status, and (8) implementation schedule. Missing or inadequate data in any of these sections triggers a return. The DPR template prescribed by MNRE differs by scheme: PM-KUSUM, SECI utility-scale and rooftop subsidy have different format requirements.

This guide is written for Indian utility-scale developers and covers the format, data sources, and quality checks needed to prepare a DPR that passes MNRE review in 2026.

Why Solar DPRs Get Returned: The Most Common Failure Modes

In practice, the same five problems cause most returned DPRs:

1. Inadequate solar resource data (free or unvalidated meteo sources, no soiling basis)
2. Missing or stale grid connectivity approvals
3. Equipment that is not on the current ALMM list or lacks BIS registration evidence
4. A financial model that does not follow the scheme or lender format
5. Incomplete land documentation

All five are preventable with the right template and a pre-submission checklist.

Section 1: Project Overview and Promoter Details

This is the DPR cover section. MNRE reviewers use this section to verify eligibility before reading the technical content. It must contain:

1.1 Project Identification

• Project name, location (district, state), and GPS coordinates of the site boundary (centre point + corner points)
• Installed capacity (DC and AC, in kW or MW)
• Technology type (ground-mount / rooftop / floating) and module technology (mono-PERC, TOPCon, bifacial)
• Proposed commissioning date
• Applicable MNRE scheme (PM-KUSUM Component A/B/C, SECI tender reference, rooftop subsidy)

For Domestic Content Requirement (DCR)-mandated schemes such as PM-KUSUM, note the scheme classification here. It determines the ALMM and BIS documentation burden carried through the equipment BOQ later in the DPR. See our MNRE DCR compliance field guide for the full ALMM verification workflow.

1.2 Promoter / Applicant Details

• Legal entity name, PAN, GST registration
• Authorised signatory details
• Track record of previous solar projects (with commissioning certificates as annexures)
• Financial net worth certification (for utility-scale, usually CA-certified statement)

Section 2: Site Feasibility Study

This section must establish that the site is technically and legally suitable for solar development. Required elements:

2.1 Land Status

• Land ownership or lease documentation (registry deed, lease agreement)
• Land use classification (agricultural / industrial / wasteland / government)
• If agricultural land: No Objection Certificate (NOC) from the state revenue department or an agricultural land diversion order
• Survey / khasra numbers for all parcels in the project footprint

2.2 Site Technical Assessment

• Terrain assessment: slope analysis, drainage, flooding risk
• Soil bearing capacity (for ground-mount; a drone survey speeds up the topography) or structural roof assessment (for rooftop)
• Shadow-free area calculation showing the net usable area vs total site area
• Access road and logistics assessment

2.3 Grid Proximity and Evacuation

• Distance to the nearest available grid injection point (with voltage level)
• Existing capacity at the proposed injection point (STU/DISCOM capacity letter, mandatory annexure)
• Proposed evacuation line route (map with corridor, distance, and right-of-way status)

This section directly connects to the solar feasibility study process. A weak site feasibility section is one of the most common DPR rejection triggers because connectivity approval letters are frequently missing.

Section 3: Solar Resource Assessment

The solar resource section is the most technically scrutinised part of the DPR. MNRE reviewers, and any independent engineer reviewing the DPR, verify three things: data source, methodology, and output plausibility.

Commonly accepted data sources:

• Solargis Prospect or Solargis Identify: widely accepted for all project sizes
• Meteonorm 8.x or later: widely accepted, with higher uncertainty than satellite time-series data
• NASA POWER: suitable for pre-feasibility only, not the final DPR
• On-site irradiance measurement (ideally 12 months or more): highest credibility, and often requested by lenders on large projects

Required Outputs:

• Global Horizontal Irradiance (GHI), annual and monthly (see GHI, DNI and DHI data for India)
• Direct Normal Irradiance (DNI), for tracker and bifacial projects
• Diffuse Horizontal Irradiance (DHI)
• Temperature data (ambient, daily max/min, monthly averages)
• Wind speed and direction (for Faiman thermal model in PVsyst)
• Soiling assessment (monthly soiling loss rate derived from site data or validated regional database)

Section 4: Technical Design

This is the largest section and requires the most engineering effort. For MNRE submission, the technical design section must include:

4.1 PVsyst Energy Yield Simulation

• PVsyst simulation report (full output, not summary): P50 and P90 annual yield, monthly generation profile, loss diagram, horizon file, 25-year degradation-adjusted yield table
• Simulation input summary table: module model, inverter model, tilt, azimuth, pitch, GCR, soiling loss profile, albedo, meteo data source, PVsyst version
• P50/P90 analysis with uncertainty quantification methodology

4.2 Equipment Bill of Quantities (BOQ) The BOQ must include:

• Solar PV modules: make, model, wattage, quantity, with BIS registration (IS 14286 / IS/IEC 61730) and ALMM List-I reference
• Inverters: make, model, kW rating, quantity, with BIS registration (IS 16221 Parts 1 and 2)
• Mounting structure: type (fixed tilt / tracker), material (hot-dip galvanised steel), foundation type
• Cables: DC (class 2 solar cable, rated 1500V DC), AC cables, earthing cable
• Protection equipment: SPDs, fuses, combiner boxes, RMU
• Metering: energy meter of the accuracy class required by the CEA metering regulations and the DISCOM

4.3 Electrical Drawings The DPR must include a preliminary single-line diagram (SLD) showing:

• DC stringing layout (number of strings per MPPT), designed in line with PV array design conventions such as IEC 62548
• Inverter configuration (string vs central)
• Step-up transformer
• Grid interconnection to injection point
• Metering and protection scheme

4.4 Civil and Structural Assessment

• Structural foundation design basis (IS 875 Part 3 wind load calculation)
• Soil investigation report (for ground-mount above 1 MW)
• Mounting structure design basis (material grade, corrosion protection specification)

Section 5: Financial Analysis

The financial section must follow MNRE’s prescribed financial model format for the applicable scheme. Key elements:

5.1 Project Cost

Component	Unit	Quantity	Rate	Amount (₹ Cr)
Solar modules	₹/Wp	Wp	Mkt rate	X
Inverters	₹/kW	kW	Mkt rate	X
Mounting structure	₹/MW	MW	Design basis	X
Civil works	Lump sum	-	Site basis	X
Electrical and HV	₹/MW	MW	Design basis	X
SCADA and monitoring	Lump sum	-	Standard	X
Land acquisition/lease	Per acre per year	Acres	Market rate	X
Project development (incl. DPR)	% of EPC	-	3-5%	X
Total EPC cost	₹/MW	MW	-	X

5.2 Financial Ratios

For lender-financed projects (see IREDA financing criteria), the DPR typically has to demonstrate:

• Project and equity IRR against the lender’s hurdle
• Debt Service Coverage Ratio (DSCR), commonly around 1.15-1.20 minimum in each year
• Loan tenor within the lender’s limit
• Debt:equity ratio, commonly up to 75:25

These are typical market values, not published rules. Confirm current IREDA or PFC (Power Finance Corporation) norms before you build the model.

5.3 Tariff Calculations

• For SECI auctions: demonstrate that the quoted tariff is consistent with the financial model at the bid capacity factor and O&M escalation assumptions
• For PM-KUSUM: demonstrate compliance with the state-notified tariff ceiling

Section 6: Grid Connectivity Plan

This section must include:

• Copy of the Preliminary Connectivity Application (PCA) acknowledgment from the STU/DISCOM
• Proposed injection point and voltage level
• Evacuation line route map (Google Earth KMZ file or georeferenced PDF)
• Estimated evacuation infrastructure cost (transmission line + substation bay)
• Timeline for evacuation infrastructure commissioning vs project COD

If the connectivity application has progressed to an interconnection study, include the study results and any STU capacity upgrade requirements.

Section 7: Environmental Clearance

• EIA status: solar PV projects are not listed in the schedule to the EIA Notification 2006, so they normally need no prior environmental clearance. State the exemption, and note any state pollution control board consent that applies.
• Any lender-required environmental and social assessment (common for DFI-funded projects)
• Forest land diversion status (if applicable)
• Water body clearance (for floating solar, state irrigation or water resources department NOC)

The DPR-Ready Framework: An MNRE Submission Checklist

The DPR-Ready Framework is a pre-submission quality check that validates all eight sections before the DPR leaves your office.

Section 8: Implementation Schedule

The implementation schedule must show realistic milestones from DPR approval to COD:

Milestone	Months from DPR Approval
Land acquisition completion	0-3 months
Environmental clearance (if required)	0-6 months
Connectivity agreement signing	3-9 months
EPC tender award	4-8 months
Equipment procurement (modules, inverters)	5-10 months
Civil works commencement	6-10 months
Electrical installation	8-14 months
Grid connection and commissioning	12-18 months
COD declaration	13-20 months

How Heaven Designs Helps

Preparing an MNRE-compliant DPR requires coordinating 8 sections of technical, legal, financial, and environmental documentation, and getting any one section wrong can cost months. Heaven Designs delivers the technical engineering sections of the DPR (PVsyst simulation, BOQ, SLD, structural assessment) in MNRE-format, ready for the promoter’s legal and financial team to integrate.

• Solar Ground Mount Design: PVsyst simulation, BOQ, SLD, structural assessment for DPR Section 4.
• Site Survey & Land Feasibility: site technical assessment for DPR Section 2.
• Electrical CEIG Drawings: CEIG-format SLD for grid connectivity and technical design sections.
• MW-Scale PMC: DPR preparation coordination, MNRE submission management, IE review preparation.
• Download a sample deliverable: see a DPR-format PVsyst simulation report and BOQ.

Contact us to scope your DPR technical package. We reply within 1 business day.

Once your DPR is approved, the project moves to physical execution. If you need an EPC partner to construct the site, Heaven Green Energy’s ground mount solar park EPC team can take the approved technical package through to commissioning.

FAQ

What is the difference between a DPR for PM-KUSUM and a DPR for a SECI tender?

PM-KUSUM DPRs typically follow the scheme-specific format prescribed by the respective state nodal agency (e.g., RRECL for Rajasthan, MNRE for central component). The financial analysis focuses on the PM-KUSUM tariff ceiling and subsidy component.

SECI DPRs follow the SECI tender RFP format, with the financial analysis focused on the bid tariff and the technical specifications aligned with SECI’s quality requirements. Both require the same core technical sections (PVsyst, BOQ, SLD), but the format and financial model differ.

How long does it take for MNRE to approve a DPR once submitted?

Timelines depend on the scheme, the reviewing agency and the DPR quality. A complete DPR that passes first review often clears in a few months. DPRs with missing connectivity documentation or inadequate solar resource data can take 6-12 months if corrections require new connectivity applications or new meteo data procurement.

What financial model format does MNRE require for IREDA-financed projects?

IREDA requires the financial model in a specific Excel format that it provides to applicants. The model must include: project cost (equipment-wise), financing structure (debt:equity, loan tenor, interest rate), revenue projections (generation × tariff, year-by-year for the loan tenor), O&M cost escalation (typically 5% per year), and financial ratios (IRR, DSCR, NPV).

The financial model must be submitted as the original Excel file (not a PDF) to allow IREDA’s financial team to verify formulas and assumptions.

Can I submit a DPR without all land documents if some land acquisition is pending?

No. MNRE requires clear land status at the time of DPR submission. For projects on government-leased land, the lease agreement or allotment letter must be submitted. For projects on private land, the registered sale deed or registered lease agreement is required. Projects with partial land acquisition pending are typically not eligible for scheme approval until 100% of the required land is secured.

What PVsyst inputs does MNRE specifically check in the technical review?

The most commonly checked PVsyst inputs are: meteo data source (a bankable source such as Solargis or Meteonorm is expected), soiling loss assumptions (checked against regional norms; see this regional soiling loss guide), meter losses (must be included; their omission is a common error), and module model (must be ALMM-listed).

The 25-year degradation table is also checked to ensure Year 1 degradation is applied correctly and the table matches the module warranty document.

Does the DPR need to be prepared by a licensed engineer or certified agency?

For projects above 1 MW, the technical sections of the DPR (PVsyst simulation, structural assessment and SLD) should be prepared or reviewed by a qualified electrical and structural engineer.

MNRE does not mandate specific professional credentials for DPR preparation, but lenders such as IREDA and PFC usually appoint or approve an Independent Engineer (IE) to review it. Prepare the technical sections to the standard an IE will apply, not just the MNRE format.

What is the required PVsyst uncertainty analysis for P90 calculation in the DPR?

The P90 yield calculation requires a structured uncertainty analysis covering: meteo data uncertainty (typically lower for satellite time-series sources such as Solargis than for Meteonorm), PVsyst model accuracy uncertainty (typically ±1-2%), soiling uncertainty (±0.5-1.0%), and degradation uncertainty. The combined uncertainty (root sum of squares method) is applied to the P50 yield to derive P90.

A Gaussian distribution is assumed, with P90 corresponding to 1.28 standard deviations below P50. According to IRENA’s renewable energy cost framework, meteo data quality is the primary driver of P90 uncertainty band width.