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Comprehensive Hydropower
Development Reference

Authoritative insights sourced from NEA, DoED, and MoFE — from survey license to asset handover.

3,617 MWInstalled Capacity
14.80 NPRMax Winter Tariff
83,000 MWTheoretical Potential
30–35 YrsLicense Term
10,300+ MWPPAs Signed
NEA Live
National Peak Demand
1,958
MW
Total Energy Demand
43,271
MWh
NEA Generation
6,922
MWh
NEA Subsidiaries
6,390
MWh
IPP Generation
19,079
MWh
Import
10,831
MWh
Export
178
MWh
Interruption Loss
50
MWh
Installed Capacity
3,617
MW
nea.org.np · Latest
© 2026 Hydropedia · Data: NEA, DoED, MoFE, ERCFor reference only — verify with official sourcesPrivacy Policy
Project Development

Development Lifecycle DoEDMoFE

10-step process from company registration through survey license, environmental approval, PPA, construction, and final asset handover to GoN.

Project Development

Project Development Lifecycle

01 — REGISTRATION
Company Registration
Register at CRO, DOI, and Tax Office. FDI approval needed if foreign investment involved.
02 — SURVEY LICENSE
Survey License (DoED)
Apply to DoED with project details, maps, and water resource data. Valid up to 5 years; typically issued within 30 days.
03 — ENVIRONMENTAL
Feasibility & Environmental Study
IEE for ≤50 MW; full EIA for >50 MW. Approved by MoFE. Process takes 6–12 months.
04 — PPA
PPA Execution (NEA)
Agreement with NEA based on approved rates. Requires technical feasibility, approved IEE/EIA, and bank LOI.
05 — APPROVALS
Additional Clearances
Forestry clearance (MoFE/DFO), National Parks (DNPWC), Road Dept access, local government recommendations.
06 — FINANCING
Financial Closure
Typical debt-equity ratio: 70:30. Demonstrate minimum 30% equity at application stage.
07 — GEN LICENSE
Generation License (DoED)
Issued for 30–35 years (max 50). Issued within 120 days of complete application.
08 — CONSTRUCTION
Construction Phase
Physical work must begin within 3 months of license issue. DoED monitors compliance.
09 — OPERATION
Power Generation & Royalty
Generate and sell power under PPA. Pay capacity and energy royalty to DoED. Royalty: 50% local, 25% area, 25% population.
10 — HANDOVER
Asset Handover to GoN
After license expiry, all assets revert to Government of Nepal. Foreign-owned (>50%): mandatory free handover.
Source: DoED Electricity Act 2049 & Licensing Guidelinesdoed.gov.np ↗
Nepal Electricity Authority

NEA — Key Statistics Q2 FY 2082/83 · Dec 2025

Updated from NEA's FY 2082/83 Q2 Self-Publication (Kartik–Poush 2082 / Oct–Dec 2025).

Generation & Capacity
Total Installed Capacity (Dec 2025)3,617.54 MW
NEA own generation661.57 MW
NEA Subsidiary companies646.4 MW
Private sector hydro (IPPs)2,186.63 MW
Private solar116.94 MW
Biogas6 MW
New IPPs commissioned Q1 FY 2082/836 projects / 105.95 MW
PPAs signed total>10,300 MW
Financial Performance (Kartik–Poush 2082)
Revenue from electricity sales (billed)NPR 58.58B
— Of which from exportsNPR 20.06B
Total incomeNPR 85.31B
Pre-tax profit estimateNPR 8.06B
Cash collectedNPR 55.90B
Electricity purchase costsNPR 45.24B
Total customers (Dec 2025)6.11 million (61,13,198)
Power Trade (FY 2081/82)
Export to India2,380 GWh (+22.33% YoY)
Export to Bangladesh (first ever)40 MW · from Kartik 20, 2081
Import from India1,712 GWh
Net export balance668 GWh
Export revenueNPR 17.47B
Daily avg export (monsoon)~1,000 MW
Transmission & Future Targets
Total transmission line6,760 CKm
Lines under construction2,034 CKm
Total substation capacity14,123 MVA
Target capacity by 203528,500 MW
Target export by 203515,000 MW
Investment needed (2035)USD 46.5B
Source: NEA Self-Publication FY 2082/83 Q2 (Kartik–Poush 2082)nea.org.np ↗
NEA Power Purchase Agreement

PPA Rates & Revenue Projection Module NEA2074/01/14

Official ROR, PROR, and Storage power purchase rates based on NEA Board Decisions effective 2074/01/14. Includes an interactive lifecycle and financial calculator utilizing 3% simple escalation.

NEA Board Decision — Effective 2074/01/14
🔔
NEA Board PPA Rules (2074/01/14): Rated capacity of hydropower projects to be eligible for local currency PPA = any capacity. Rated capacity eligible for foreign currency PPA = above 100 MW. Base rate to be lowered for projects >100MW with ROE higher than 17%.
Interactive Module

PPA Revenue & Financial Projections

%
3% for 8 yrs (Simple)
Year 1
Est. Annual Revenue (Selected Year)
NPR 0.00 Cr
DSCR
0.00
Free Cash Flow
Rs. 0.00 Cr
GoN Royalty Breakdown Y1-15 Phase
Capacity Royalty0
Energy Royalty0
Total Est. Royalty0
OPEX Estimated: 0
Est. Lifecycle Revenue (All Years)
NPR 0.00 Cr
Dry Revenue Component
0
0
Wet Revenue Component
0
0
NEA Compensation
0
Deviation Penalty
0
Official Document Extracts

PPA Agreement Clauses & Schedules

Verified provisions from standard Nepal Electricity Authority (NEA) Power Purchase Agreements (PPA). Preserved in both English translation and original Nepali text.

📑 Clause 12: Electricity Purchase Rate (विद्युत खरिद मूल्यदर)

Nepali (Original)

१२.१ प्राधिकरणले व्यापारिक उत्पादन शुरु हुने मितिदेखि हरेक महिना कम्पनीले आयोजनाबाट उत्पादन गरी उपलब्ध गराएको कन्ट्रयाक्ट इनर्जीको परिमाणसम्मको उर्जा वापत निम्नानुसारको खरिद दरले हुन आउने रकम कम्पनी... बुझाउने छ ।

व्यापारिक उत्पादन शुरु हुने मिति (Commercial Operation Date) बाट एक वर्ष पुगेको महिनाको लगत्तै पछिको महिनादेखि लागु हुनेगरि प्रत्येक वर्षको लागि ३ (तीन) प्रतिशतका दरले ८ (आठ) पटकसम्म साधारण मूल्यवृद्धि दिई निम्न तालिका अनुसार विद्युत उर्जा खरिद दर कायम गरिएको छ ।

सुख्खायाम (मंसिर १६ देखि जेठ १५ सम्म): रु. ८।४० प्रति युनिट
वर्षायाम (जेठ १६ देखि मंसिर १५ सम्म): रु. ४।८० प्रति युनिट

RCOD को तुलनामा COD ढिलो हुन गएमा जम्मा मूल्यवृद्धि:
(क) ६ देखि १८ महिनासम्म ढिलो भएमा: जम्मा ७ वटा
(ख) १८ देखि ३० महिनासम्म ढिलो भएमा: जम्मा ६ वटा
(ग) ३० देखि ४२ महिनासम्म ढिलो भएमा: जम्मा ५ वटा
(घ) ४२ देखि ५४ महिनासम्म ढिलो भएमा: जम्मा ४ वटा
(ङ) ५४ महिनाभन्दा बढी ढिलो भएमा: जम्मा ३ वटा

English (Translation)

12.1 NEA shall pay the Company the amount calculated at the following purchase rates for the energy supplied up to the Contract Energy quantum from the Commercial Operation Date...

A simple price escalation of 3 (three) percent per year for up to 8 (eight) times will be provided, effective from the month immediately following the completion of one year from the Commercial Operation Date (COD).

Dry Season (Mangsir 16 to Jestha 15): Rs. 8.40 per unit
Wet Season (Jestha 16 to Mangsir 15): Rs. 4.80 per unit

If COD is delayed compared to the Required Commercial Operation Date (RCOD), escalations shall be reduced as follows:
(a) Delayed by >6 to 18 months: Max 7 escalations
(b) Delayed by >18 to 30 months: Max 6 escalations
(c) Delayed by >30 to 42 months: Max 5 escalations
(d) Delayed by >42 to 54 months: Max 4 escalations
(e) Delayed by >54 months: Max 3 escalations

⚠️ Clause 10: Deviation Penalty & Compensation (पूर्वानूमान विचलन शुल्क र क्षतिपूर्ति)

Nepali (Original)

विचलन शुल्क रु. = ०.१ *[०.९ * कम्पनीबाट प्राधिकरणलाई आपूर्ति हुनु पर्ने बढीमा कन्ट्रयाक्ट इनर्जी सम्मको Availability Declaration अनुसारको मासिक विद्युत उर्जा - सोही महिनामा कम्पनीले उपलब्ध गराएको उर्जा - सोही अवधिमा प्राधिकरणको कारणले वा Scheduled Outage वा काबू बाहिरको परिस्थितिको कारणले आयोजनाबाट उपलब्ध हुन नसकेको उर्जा] * सो महिनाको विद्युत खरिद दर;

English (Translation)

Deviation Penalty (Rs.) = 0.1 *[0.9 * Monthly energy declared (up to Contract Energy) - Energy actually supplied - Energy undelivered due to NEA/Force Majeure/Scheduled Outage] * Purchase Price for that month;

📖 Article 1: Key Technical Definitions (प्राविधिक परिभाषाहरु)

Nepali (Original)

डेलिभरी प्वाइन्ट (Delivery Point): आयोजनाबाट उत्पादन हुने विद्युत शक्ति प्राधिकरणलाई उपलब्ध गराउने विन्दु (सबस्टेशनको बसबार)।

व्यापारिक उत्पादन शुरु हुने मिति (COD): आयोजनाबाट प्रथम पटक उत्पादन गरी १५ दिनको सन्तोषजनक परीक्षण उत्पादन (Test Generation) सम्पन्न भएको मिति।

फोर्स आउटेज (Forced Outage): प्राधिकरणको विद्युत प्रणालीमा ट्रिपिङ्ग वा गडबडी भई विद्युत लिन नसकेको अवस्था (काबू बाहिरको परिस्थिति बाहेक)।

प्रसारण सुविधाहरु (Interconnection Facilities): विद्युत केन्द्रदेखि डेलिभरी प्वाइन्टसम्मको प्रसारण लाइन, स्वीचयार्ड, मिटरिङ्ग प्रणाली आदि।

English (Translation)

Delivery Point: The designated NEA substation busbar where the generated electricity is handed over.

Commercial Operation Date (COD): The date commercial generation commences following a successful 15-day continuous test generation period.

Forced Outage: An unexpected interruption in power evacuation caused by NEA grid faults, tripping, or system failures (excluding Force Majeure conditions).

Prudent Utility Practices: Internationally accepted engineering and utility standards for hydropower operation, design, and maintenance.

🗓️ Schedule 2: Contract Energy

Contract Energy is declared via the Availability Declaration. For ROR projects, the minimum dry season energy must be 30% to avoid financial penalties. The table defines the monthly dispatched energy (kWh) distributed across Dry (Mangsir 16 to Jestha 15) and Wet (Jestha 16 to Mangsir 15) seasons.

💰 Schedule 3: Compensation Formula (Case I & Case II)

Case I: Forced Outage of NEA Line(s)

Applies when grid faults prevent the Project from generating/delivering according to Available Capacity.

UE = ∑ (UC_i × PT_i)

UC_i (Undelivered Capacity) = Available Capacity - Capacity Delivered (0 if negative).
PT_i (Prorated Time) = [UC_i / Monthly Capacity]* × Forced Outage Hours.

*Applicable only to the extent that (Metered Energy + UE) is equal to or less than 80% of the smaller of Contract Energy and Availability Declaration for the Month.

Case II: NEA Dispatch Instructions

Applies when NEA instructs the Project to generate less than the Available Capacity.

UE = ∑ (UC_i × PT_i)

UC_i = Available Capacity - (the greater of Capacity Dispatched and Capacity Delivered).
PT_i = [UC_i / Monthly Capacity]* × Nondispatched Hours.

Zero Compensation Exceptions:
Compensation = 0 if cumulative PT ≤ 72 hours in the Fiscal Year, OR if dispatched & delivered energy ≥ 100% of the smaller of Contract Energy and Availability Declaration.

ROR Rates — Up to 100 MW

OptionSeasonPeriodRate (Rs./kWh)Min. Dry Energy
Option 1
(6 months each)		WetJestha 16 – Mangsir 154.8030%
DryMangsir 16 – Jestha 158.40
Option 2
(4 Dry / 8 Wet)		WetBaisakh – Mangsir4.8015%
DryPoush – Chaitra8.40
Note: Posted rate with 3% simple escalations for 8 years for capacity up to 100 MW. Base rate to be lowered for projects above 100 MW with ROE higher than 17%.

PROR Rates — Peaking Run of River

SeasonTime of DayDaily Hours required to generate at rated capacityRate (Rs./kWh)Min. Dry Energy
Dry
(Mangsir 16 - Jestha 15)		Peak hours1 hr to <2 hrs8.5030%
2 hrs to <3 hrs8.80
3 hrs to <4 hrs9.40
4 hrs to 6 hrs10.55
Non-peak hoursAll other hours8.40
Wet
(Jestha 16 - Mangsir 15)		All hours-4.80-

STORAGE PROJECT RATES

SeasonPeriodRate (Rs./kWh)Min. Dry Energy
DryMangsir 16 – Jestha 1512.4035%
WetJestha 16 – Mangsir 157.10*-
Storage Rules: 3% simple escalations for 8 years. If dry season energy is less than 35% of annual energy, treated as PROR.
Source: NEA Board Decisions 2074/01/14nea.org.np ↗
NEA Power Purchase Agreement

PPA Rates & Revenue Projection Module NEA2074/01/14

Official ROR, PROR, and Storage power purchase rates based on NEA Board Decisions effective 2074/01/14. Includes an interactive lifecycle and financial calculator utilizing 3% simple escalation.

NEA Board Decision — Effective 2074/01/14
🔔
NEA Board PPA Rules (2074/01/14): Rated capacity of hydropower projects to be eligible for local currency PPA = any capacity. Rated capacity eligible for foreign currency PPA = above 100 MW. Base rate to be lowered for projects >100MW with ROE higher than 17%.
Interactive Module

PPA Revenue & Financial Projections

%
3% for 8 yrs (Simple)
Year 1
Est. Annual Revenue (Selected Year)
NPR 0.00 Cr
DSCR
0.00
Free Cash Flow
Rs. 0.00 Cr
GoN Royalty Breakdown Y1-15 Phase
Capacity Royalty0
Energy Royalty0
Total Est. Royalty0
OPEX Estimated: 0
Est. Lifecycle Revenue (All Years)
NPR 0.00 Cr
Dry Revenue Component
0
0
Wet Revenue Component
0
0
NEA Compensation
0
Deviation Penalty
0
Official Document Extracts

PPA Agreement Clauses & Schedules

Verified provisions from standard Nepal Electricity Authority (NEA) Power Purchase Agreements (PPA). Preserved in both English translation and original Nepali text.

📑 Clause 12: Electricity Purchase Rate (विद्युत खरिद मूल्यदर)

Nepali (Original)

१२.१ प्राधिकरणले व्यापारिक उत्पादन शुरु हुने मितिदेखि हरेक महिना कम्पनीले आयोजनाबाट उत्पादन गरी उपलब्ध गराएको कन्ट्रयाक्ट इनर्जीको परिमाणसम्मको उर्जा वापत निम्नानुसारको खरिद दरले हुन आउने रकम कम्पनी... बुझाउने छ ।

व्यापारिक उत्पादन शुरु हुने मिति (Commercial Operation Date) बाट एक वर्ष पुगेको महिनाको लगत्तै पछिको महिनादेखि लागु हुनेगरि प्रत्येक वर्षको लागि ३ (तीन) प्रतिशतका दरले ८ (आठ) पटकसम्म साधारण मूल्यवृद्धि दिई निम्न तालिका अनुसार विद्युत उर्जा खरिद दर कायम गरिएको छ ।

सुख्खायाम (मंसिर १६ देखि जेठ १५ सम्म): रु. ८।४० प्रति युनिट
वर्षायाम (जेठ १६ देखि मंसिर १५ सम्म): रु. ४।८० प्रति युनिट

RCOD को तुलनामा COD ढिलो हुन गएमा जम्मा मूल्यवृद्धि:
(क) ६ देखि १८ महिनासम्म ढिलो भएमा: जम्मा ७ वटा
(ख) १८ देखि ३० महिनासम्म ढिलो भएमा: जम्मा ६ वटा
(ग) ३० देखि ४२ महिनासम्म ढिलो भएमा: जम्मा ५ वटा
(घ) ४२ देखि ५४ महिनासम्म ढिलो भएमा: जम्मा ४ वटा
(ङ) ५४ महिनाभन्दा बढी ढिलो भएमा: जम्मा ३ वटा

English (Translation)

12.1 NEA shall pay the Company the amount calculated at the following purchase rates for the energy supplied up to the Contract Energy quantum from the Commercial Operation Date...

A simple price escalation of 3 (three) percent per year for up to 8 (eight) times will be provided, effective from the month immediately following the completion of one year from the Commercial Operation Date (COD).

Dry Season (Mangsir 16 to Jestha 15): Rs. 8.40 per unit
Wet Season (Jestha 16 to Mangsir 15): Rs. 4.80 per unit

If COD is delayed compared to the Required Commercial Operation Date (RCOD), escalations shall be reduced as follows:
(a) Delayed by >6 to 18 months: Max 7 escalations
(b) Delayed by >18 to 30 months: Max 6 escalations
(c) Delayed by >30 to 42 months: Max 5 escalations
(d) Delayed by >42 to 54 months: Max 4 escalations
(e) Delayed by >54 months: Max 3 escalations

⚠️ Clause 10: Deviation Penalty & Compensation (पूर्वानूमान विचलन शुल्क र क्षतिपूर्ति)

Nepali (Original)

विचलन शुल्क रु. = ०.१ *[०.९ * कम्पनीबाट प्राधिकरणलाई आपूर्ति हुनु पर्ने बढीमा कन्ट्रयाक्ट इनर्जी सम्मको Availability Declaration अनुसारको मासिक विद्युत उर्जा - सोही महिनामा कम्पनीले उपलब्ध गराएको उर्जा - सोही अवधिमा प्राधिकरणको कारणले वा Scheduled Outage वा काबू बाहिरको परिस्थितिको कारणले आयोजनाबाट उपलब्ध हुन नसकेको उर्जा] * सो महिनाको विद्युत खरिद दर;

English (Translation)

Deviation Penalty (Rs.) = 0.1 *[0.9 * Monthly energy declared (up to Contract Energy) - Energy actually supplied - Energy undelivered due to NEA/Force Majeure/Scheduled Outage] * Purchase Price for that month;

📖 Article 1: Key Technical Definitions (प्राविधिक परिभाषाहरु)

Nepali (Original)

डेलिभरी प्वाइन्ट (Delivery Point): आयोजनाबाट उत्पादन हुने विद्युत शक्ति प्राधिकरणलाई उपलब्ध गराउने विन्दु (सबस्टेशनको बसबार)।

व्यापारिक उत्पादन शुरु हुने मिति (COD): आयोजनाबाट प्रथम पटक उत्पादन गरी १५ दिनको सन्तोषजनक परीक्षण उत्पादन (Test Generation) सम्पन्न भएको मिति।

फोर्स आउटेज (Forced Outage): प्राधिकरणको विद्युत प्रणालीमा ट्रिपिङ्ग वा गडबडी भई विद्युत लिन नसकेको अवस्था (काबू बाहिरको परिस्थिति बाहेक)।

प्रसारण सुविधाहरु (Interconnection Facilities): विद्युत केन्द्रदेखि डेलिभरी प्वाइन्टसम्मको प्रसारण लाइन, स्वीचयार्ड, मिटरिङ्ग प्रणाली आदि।

English (Translation)

Delivery Point: The designated NEA substation busbar where the generated electricity is handed over.

Commercial Operation Date (COD): The date commercial generation commences following a successful 15-day continuous test generation period.

Forced Outage: An unexpected interruption in power evacuation caused by NEA grid faults, tripping, or system failures (excluding Force Majeure conditions).

Prudent Utility Practices: Internationally accepted engineering and utility standards for hydropower operation, design, and maintenance.

🗓️ Schedule 2: Contract Energy

Contract Energy is declared via the Availability Declaration. For ROR projects, the minimum dry season energy must be 30% to avoid financial penalties. The table defines the monthly dispatched energy (kWh) distributed across Dry (Mangsir 16 to Jestha 15) and Wet (Jestha 16 to Mangsir 15) seasons.

💰 Schedule 3: Compensation Formula (Case I & Case II)

Case I: Forced Outage of NEA Line(s)

Applies when grid faults prevent the Project from generating/delivering according to Available Capacity.

UE = ∑ (UC_i × PT_i)

UC_i (Undelivered Capacity) = Available Capacity - Capacity Delivered (0 if negative).
PT_i (Prorated Time) = [UC_i / Monthly Capacity]* × Forced Outage Hours.

*Applicable only to the extent that (Metered Energy + UE) is equal to or less than 80% of the smaller of Contract Energy and Availability Declaration for the Month.

Case II: NEA Dispatch Instructions

Applies when NEA instructs the Project to generate less than the Available Capacity.

UE = ∑ (UC_i × PT_i)

UC_i = Available Capacity - (the greater of Capacity Dispatched and Capacity Delivered).
PT_i = [UC_i / Monthly Capacity]* × Nondispatched Hours.

Zero Compensation Exceptions:
Compensation = 0 if cumulative PT ≤ 72 hours in the Fiscal Year, OR if dispatched & delivered energy ≥ 100% of the smaller of Contract Energy and Availability Declaration.

ROR Rates — Up to 100 MW

OptionSeasonPeriodRate (Rs./kWh)Min. Dry Energy
Option 1
(6 months each)		WetJestha 16 – Mangsir 154.8030%
DryMangsir 16 – Jestha 158.40
Option 2
(4 Dry / 8 Wet)		WetBaisakh – Mangsir4.8015%
DryPoush – Chaitra8.40
Note: Posted rate with 3% simple escalations for 8 years for capacity up to 100 MW. Base rate to be lowered for projects above 100 MW with ROE higher than 17%.

PROR Rates — Peaking Run of River

SeasonTime of DayDaily Hours required to generate at rated capacityRate (Rs./kWh)Min. Dry Energy
Dry
(Mangsir 16 - Jestha 15)		Peak hours1 hr to <2 hrs8.5030%
2 hrs to <3 hrs8.80
3 hrs to <4 hrs9.40
4 hrs to 6 hrs10.55
Non-peak hoursAll other hours8.40
Wet
(Jestha 16 - Mangsir 15)		All hours-4.80-

STORAGE PROJECT RATES

SeasonPeriodRate (Rs./kWh)Min. Dry Energy
DryMangsir 16 – Jestha 1512.4035%
WetJestha 16 – Mangsir 157.10*-
Storage Rules: 3% simple escalations for 8 years. If dry season energy is less than 35% of annual energy, treated as PROR.
Source: NEA Board Decisions 2074/01/14nea.org.np ↗
Department of Electricity Development

DoED — Licensing Framework DoED

Survey license and generation license process, document requirements, royalty structure, and fiscal incentives.

1
Pre-Application Consultation
Engage DoED for guidance.
2
Survey License Application
Submit docs, MOA/AOA, financial capacity.
3
DoED Review & Field Visit
Site visit + 35-day objection window.
4
Survey License Issued
Within 30 days. Valid 2–5 years.
5
Generation License Application
DPR, EIA, financial closure, PPA.
6
Generation License Issued
Within 120 days. Valid 35 years (max 50).
Survey License Requirements
  • Certificate of Incorporation (OCR)
  • MOA / AOA of applicant company
  • Citizenship certificates of all directors
  • Board resolution for application
  • Financial capability / bank guarantees
  • Technical proposal with river system, location, capacity
  • Topographic maps of project site
  • Application fee (15% of license fee)
Generation License Requirements
  • Valid Survey License (certified copy)
  • Detailed Project Report (DPR) per DoED guidelines
  • Approved IEE or EIA report
  • Signed PPA with NEA
  • Financial closure evidence (30% equity min.)
  • Land ownership/lease certificates
  • Affected community consent letters
  • Application fee (33.33% of license fee)
License Timelines & Validity
  • Survey License: within 30 days
  • Survey License validity: 2 years (max 5)
  • Generation License: within 120 days
  • Generation License term: 35 years (max 50)
  • Construction must begin within 3 months
  • 100% foreign investment permitted

Royalty Structure

Capacity Royalty

PeriodRate / kW / year
First 15 yearsNPR 100
After 15 yearsNPR 1,000

Energy Royalty

Period% of Average Tariff
First 15 years2%
After 15 years10%
Source: Electricity Act 2049, Electricity Rules 2050, DoED Guidelinesdoed.gov.np ↗
Ministry of Forests and Environment

MoFE — Environmental Clearance MoFE / DoE

EIA/IEE thresholds, MoFE approval process, forest and protected area clearances, and key environmental legislation.

<1 MW
Micro Hydro
No IEE/EIA required. Local government oversight. DoED permission still required.
1 – 50 MW
IEE Required
Initial Environmental Examination. Approved by MoEWRI. Public consultation mandatory >5 MW.
>50 MW
Full EIA Required
Approved by MoFE. Process: 6–12 months. In Protected Areas: EIA required above 10 MW.
🔍
Screening & Scoping
~2–4 weeks
📋
TOR Approval
MoFE review
🏕️
Field Study
~3–6 months
📢
15-Day Public Notice
National newspaper
🤝
Public Hearing
Project-affected VDC
📨
EIA Submission
30-day review
✅
Final Approval
MoFE decision

🌲 Forest & Protected Area Clearances

  • Forest clearance if project land is forest area
  • National Parks require DNPWC clearance
  • In protected areas: EIA for >10 MW
  • Tree planting ratio: 1:10 (compensatory afforestation)

🌊 Environmental Management Plan

  • EMP monitored by MoEWRI
  • Developer must implement per approved EIA/IEE
  • Minimum environmental flow (e-flow) mandatory downstream
  • Annual environmental monitoring report required

📄 Key Environmental Laws

  • Environment Protection Act 2076 (2019)
  • Environment Protection Rules 2077 (2020)
  • Water Resources Act 2049 (1992)
  • Forest Act 2019
  • National Parks and Wildlife Protection Act 1973

⏱️ Typical Timeline

  • IEE (≤50 MW): 3–6 months from submission
  • EIA (>50 MW): 6–12 months
  • Forest clearance: additional 2–4 months
  • Protected area clearance: additional 3–6 months
Source: Environment Protection Act 2076, Environment Protection Rules 2077mofe.gov.np ↗
Legal & Regulatory

Legal Framework & Classifications

Hydropower classification tables, core Acts and Regulations, and regulatory body responsibilities.

Administrative Classification

CategoryCapacityRegulatory Body
Micro Hydro<1 MWLocal Government / Ward Office
Small Hydro1–10 MWDoED (simplified process)
Medium Hydro10–25 MWDoED (standard process)
Large Hydro25–500 MWDoED / Cabinet approval
Mega Projects>500 MWInvestment Board of Nepal (IBN)

Classification by Head

TypeHead Range
Very Low HeadUp to 15 m
Low HeadBelow 60 m
Medium Head60–150 m
High Head150–350 m
Very High Head>350 m
Act / RegulationYearKey Provisions
Electricity Act (2049)1992Primary legislation — licensing, GoN nationalization rights, license transfer
Electricity Rules (2050)1993Detailed procedures for survey/generation licenses, royalty schedule
Water Resources Act (2049)1992Regulates use of water resources for hydropower generation
Environment Protection Act (2076)2019Mandates EIA/IEE for development projects
Hydropower Development Policy2001Royalty structure, foreign investment rules, right of reversion
NEA Board Decisions2017Differentiated PPA rates for ROR, PROR, and Reservoir-based projects
Source: Electricity Act 2049, Water Resources Act 2049, EPA 2076
Nepal Electricity Authority

Consumer Tariff Rates & Estimator NEA 2026

Official electricity tariff for domestic, commercial, industrial and special categories. Interactive bill estimator included. Translated from the official NEA tariff PDF.

Interactive Calculator

NEA Electricity Bill Estimator

⚡ 5A Single Phase Domestic
Total Monthly Payable
NPR 0.00
Energy: Rs. 0.00 Fixed: Rs. 0.00

Calculation Breakdown

1. Domestic Sector
1.1 Single Phase Low Voltage (230V)
Units (kWh) / Month 5 Ampere 15 Ampere 30 Ampere 60 Ampere
Min Charge (Rs.)Energy Rate (Rs.) Min Charge (Rs.)Energy Rate (Rs.) Min Charge (Rs.)Energy Rate (Rs.) Min Charge (Rs.)Energy Rate (Rs.)
0 - 20300.00*504.00755.001256.00
21 - 30506.50756.501006.501256.50
31 - 50508.00758.001008.001258.00
51 - 100759.501009.501259.501509.50
101 - 2501009.501259.501509.502009.50
Above 25015011.0017511.0020011.0025011.00
Note: *For 5 Ampere customers, if monthly consumption exceeds 20 kWh, the energy charge for the first 1 to 20 units will be calculated at Rs. 3.00 per unit.
1.2 Three-Phase Low Voltage (400V)
CategoryMin Charge (Rs.)Energy Rate (Rs./Unit)
Ashad-KattikMangsir-Jestha
Up to 10 kVA1,10010.5011.50
Above 10 kVA1,80010.5011.50
1.3 Three-Phase Medium Voltage (33/11 kV)
CategoryMin Charge (Rs.)Energy Rate (Rs./Unit)
Ashad-KattikMangsir-Jestha
Any Usage10,00010.5011.00
2. Other Consumers
2.1 Low Voltage Level (230/400 Volt)
Consumer CategoryDemand/Min Charge (Rs. / kVA / Month)Energy Rate (Rs. / Unit)
1. Industrial
a. Rural and Cottage Industry607.80
b. Small Industry1109.60
2. Commercial32511.20
3. Non-Commercial21512.00
4. Irrigation02.25
5. Water Supply
a. Community Water Supply04.20
b. Other Water Supply1607.20
6. Transport (Including Charging Stations)
a. Public Transport2005.75
b. Other Transport2208.90
7. Religious Places06.10
8. Street Light
a. Meter Installed07.30
b. Meter Not Installed2,4750.00
9. Temporary Connection019.80
10. Non-Domestic35013.00
11. Entertainment Business35014.00
2.2 Medium & High Voltage Level
Consumer CategoryDemand Charge (Rs. / kVA / Month)Energy Rate (Rs. / Unit)
A. High Voltage
1. Industrial (132 kV)2308.20
2. Industrial (66 kV)2408.30
B. Medium Voltage (33 kV)
1. Industrial2558.40
2. Commercial31510.80
3. Non-Commercial24011.40
4. Irrigation02.50
5a. Community Water Supply04.60
5b. Other Water Supply1606.60
6a. Transport (Public)2305.60
6b. Transport (Other)2558.60
7. Non-Domestic35012.55
8. Entertainment Business35013.50
C. Medium Voltage (11 kV)
1. Industrial2558.60
2. Commercial31511.10
3. Non-Commercial24011.50
4. Irrigation02.60
5a. Community Water Supply04.80
5b. Other Water Supply1506.80
6a. Transport (Public)2305.60
6b. Transport (Other)2558.80
7. Religious Places2209.90
8. Temporary Connection33012.00
9. Non-Domestic35012.90
10. Entertainment Business35013.90
3. Time of Day (ToD) Tariff
3.1 Summer Season (Baishakh to Mangsir)
Consumer Category Demand Charge (Rs.) Energy Rate (Rs. / Unit)
Peak (17:00 - 23:00) Off-Peak (23:00 - 05:00) Normal (05:00 - 17:00)
A. High Voltage
1. Industrial (132 kV)23010.004.658.20
2. Industrial (66 kV)24010.104.758.30
B. Medium Voltage (33 kV)
1. Industrial25010.205.258.40
2. Commercial31512.306.7510.80
3. Non-Commercial24013.207.0012.00
4. Irrigation06.302.003.00
5a. Community Water06.203.104.60
5b. Other Water Supply15010.205.258.40
6a. Transport (Charging Station)2307.003.705.50
6b. Transport (Other)2559.353.708.40
7. Street Light808.403.504.20
C. Medium Voltage (11 kV)
1. Industrial25010.505.408.55
2. Commercial31512.606.9011.10
3. Non-Commercial24013.507.1512.25
4. Irrigation06.402.003.10
5a. Community Water06.303.404.70
5b. Other Water Supply15010.505.408.50
6a. Transport (Charging Station)2307.154.205.60
6b. Transport (Other)2559.654.208.50
7. Street Light808.803.754.40
8. Religious Places22011.305.159.10
9. Temporary Connection33014.406.6011.75
D. Low Voltage (230/400 Volt)
1a. Transport (Charging Station)2007.254.305.75
1b. Transport (Other)2209.754.308.60
3.2 Winter Season (Poush to Chaitra)
Consumer Category Demand Charge (Rs.) Energy Rate (Rs. / Unit)
Peak (17:00 - 23:00) Other Times (23:00 - 17:00 Next Day)
A. High Voltage
1. Industrial (132 kV)23010.008.20
2. Industrial (66 kV)24010.108.30
B. Medium Voltage (33 kV)
1. Industrial25010.208.40
2. Commercial31512.3010.80
3. Non-Commercial24013.2012.00
4. Irrigation06.303.00
5a. Community Water06.204.60
5b. Other Water Supply15010.208.40
6a. Transport (Charging Station)2307.005.50
6b. Transport (Other)2559.358.40
7. Street Light808.404.20
C. Medium Voltage (11 kV)
1. Industrial25010.508.55
2. Commercial31512.6011.10
3. Non-Commercial24013.5012.25
4. Irrigation06.403.10
5a. Community Water06.304.70
5b. Other Water Supply15010.508.50
6a. Transport (Charging Station)2307.155.60
6b. Transport (Other)2559.658.50
7. Street Light808.804.40
8. Religious Places22011.309.10
9. Temporary Connection33014.4011.75
D. Low Voltage (230/400 Volt)
1a. Transport (Charging Station)2007.255.75
1b. Transport (Other)2209.758.60
Note: Public transport (charging stations) can add a maximum premium of 20% over the standard tariff above when billing their customers. Valid for trolley buses, electric buses/minibuses, safa tempos, and battery charging operations.
4. Community Wholesale
Community Wholesale Consumers
Voltage LevelMonthly Minimum Charge (Rs.)Energy Rate (Rs. / Unit)
A. Medium Voltage (11 kV / 33 kV)
N x 20 Units (Monthly)N x 300.00
Above N x 20 Units (Monthly)-6.00
B. Low Voltage (230/400 Volt)
N x 20 Units (Monthly)N x 300.00
Above N x 20 Units (Monthly)-6.25
N = Total number of consumers under the respective community wholesale group.
5. Service Fees
Administrative & Other Service Charges
Service DescriptionRate (Rs.)
1. Application Form
a) Domestic100
b) Other Customers200
c) Application for other purposes10
2. Fuse Service
a) Single Phase100
b) Three Phase200
3. Meter Sealing
a) Box Seal (On customer request)200
a) Box Seal (Discovered by Office)500
b) Terminal Seal400
c) Reading Seal1000
d) CT/PT Seal1000
4. New Meter Installation (Energy Meter Capacity)
a) 5 Ampere100
b) 15 Ampere150
c) 30 Ampere300
d) 60 Ampere500
e) Three Phase1000
f) Up to 10 kVA (Other Customer)1000
g) Above 10 kVA (Other Customer)1500
h) Time of Day (ToD) Meter1500
5. Pole Installation (If Required)
a) Single Phase (per pole)500
b) Three Phase (per pole)1000
6. Meter Capacity Change
a) Capacity Upgrade (Single & Three Phase)0
b) Capacity Downgrade (Single Phase)300
c) Capacity Downgrade (Three Phase)500
7. Electricity Supply Cut & Reconnect
a) Line Cut250
b) Line Reconnect500
8. Meter Relocation
a) Single Phase700
b) Three Phase1000
9. Ownership/Name Transfer
a) Domestic (Inheritance with written proof)500
b) Domestic (House sale - mutual agreement)1000
c) Domestic (Sale with public notice requirement)1500
d) Industrial & Others2000
10. Meter Testing
a) Single Phase500
b) Three Phase1000
c) ToD Meter2000
d) Sub-meter500
e) CT Meter1500
11. De-registration (Lagat Kharej)
a) Single Phase500
b) Three Phase1000
Billing & Services
NEA Online Billing & Consumer Services
Check & Pay Your Bill
Online bill checkneabilling.com ↗
Bill paymentnea.org.np/payment ↗
Complaint portalcrm.nea.org.np ↗
New Connection
New customer applicationnea.org.np/new-customer ↗
Meter transfernea.org.np/meter-transfer ↗
NEA Mobile Apps
NEA App (Android)Google Play ↗
NEA App (iOS)App Store ↗
NEA Head Office977-1-4153051 · Durbarmarg, KTM
Source: nea.org.np/pages/consumer-tariff-rates ↗ · Download PDF ↗ nea.org.np/en ↗
Nepal Electricity Authority

NEA Report — FY 2081/82 & Q2 FY 2082/83 NEA Updated Dec 2025

NEA Annual Report FY 2081/82 + Q2 FY 2082/83 Self-Publication (Oct–Dec 2025). Capacity: 3,617.54 MW. Customers: 6.11 million. Data from nea.org.np/en.

Auto-updating from nea.org.np · Last fetch: Loading…
Installed Capacity (Dec 2025)
3,617.54 MW
↑ 105.95 MW added Q1 FY 2082/83
Total Energy Available
15,641 GWh
NEA 34% · IPP 55% · Import 11%
Cash Collected Q2
NPR 55.90B
Kartik–Poush 2082
Net Export (FY 2081/82)
668 GWh
Export 2,380 · Import 1,712 GWh
Peak Demand
2,901 MW
Record — Ashad 18, 2082
Total Customers
6.11 M
61,13,198 · as of Dec 2025
Live Energy Details — from nea.org.np/en
Latest data
National Peak Demand
1,958
MW
NEA Generation
6,922
MWh
NEA Subsidiaries
6,390
MWh
IPP Generation
19,079
MWh
Import from India
10,831
MWh
Export
178
MWh
Interruption Loss
50
MWh
Total Energy Demand
43,271
MWh
Data from nea.org.np/en Energy Details section. Latest auto-publication: Details of major activities up to Poush 2082 (Apr 9, 2026)
Official Publications
NEA Annual Reports & Magazines nea.org.np/en/category/annual-reports
📅
NEA published four new reports in April 2026: Vidyut 2082, NEA DCSD Magazine 2082, Transmission Directorate Report 2082, and Generation Directorate Report 2081/82. The Annual Report 2024/2025 was published October 2025.
Generation Directorate
Power Generation — FY 2081/82 NEA
⚡
Total installed capacity reached 3,617.54 MW as of December 2025. FY 2081/82: national system accessed 15,641 GWh; domestic consumption grew 10.7% to 11,319 GWh. Peak demand: 2,901 MW on Ashad 18, 2082.
Installed Capacity Breakdown (Dec 2025)
Total Installed Capacity3,617.54 MW
NEA own (hydro + solar + thermal)661.57 MW
NEA Subsidiary companies646.4 MW
Private hydro (IPPs)2,186.63 MW
Private solar116.94 MW
Biogas6 MW
New IPPs commissioned Q1 FY 2082/836 projects / 105.95 MW
Energy Generation & Availability (FY 2081/82)
Total energy available15,641 GWh
— IPP share (55%)~8,603 GWh
— NEA + Subsidiaries (34%)~5,318 GWh
— Import from India (11%)1,712 GWh
Domestic consumption11,319 GWh (+10.7% YoY)
Peak demand (Ashad 18, 2082)2,901 MW
Power Trade
Electricity Export & Import — FY 2081/82 Historic Year
🇧🇩
Bangladesh Export — First Ever
40 MW
Nepal exported to Bangladesh via Indian grid from Kartik 20, 2081. Tripartite milestone.
📈
Export to India — YoY Growth
+22.33%
Total export reached 2,380 GWh. India approved 1,010 MW from 30 projects.
⚖️
Net Power Trade Balance
668 GWh
Export 2,380 GWh minus import 1,712 GWh. Export revenue: NPR 17.47B.
Financial Performance
Financial Results — FY 2081/82 NEA Annual Report
Revenue from Sales
NPR 125.27B
↑ 8.46% YoY
Total Revenue
NPR 138.87B
All income sources
Pre-Tax Profit
NPR 9.06B
↓ 37.32% YoY
Total Assets
NPR 684.91B
↑ 6.2% YoY
Key Milestones
FY 2081/82 — Year in Review
Baisakh 2081
20-Project Commissioning Drive — 456.45 MW Added
From Baisakh to Chaitra 2081, 20 projects (18 hydro, 2 solar) commissioned.
Kartik 2081
🇧🇩 First Electricity Export to Bangladesh — 40 MW
Launched Kartik 20 via Dhalkebar–Muzaffarpur–Baharampur–Bheramara route.
Poush 2081
Private Sector Transmission — First Ever (PPP Model)
Tamor–Dhungesanghu 220 kV line signed under PPP model.
Ashad 18, 2082
🏆 Record Peak Demand — 2,901 MW
Nepal's all-time peak demand record: 2,214 MW domestic + 687 MW exported simultaneously.
Q2 FY 2082/83 Self-Publication
NEA Quarterly Update — Kartik to Poush 2082 Oct–Dec 2025
Financial Summary (Cumulative Q1+Q2)
Export revenueNPR 20.06B (2.89 billion units)
Electricity purchased from producers8.18B units → NPR 45.24B
Revenue billedNPR 58.58B
Cash collectedNPR 55.90B
Pre-tax profit estimateNPR 8.06B
New IPPs Commissioned (Q1 FY 2082/83)
Sagu Khola HPP (Dolakha)20 MW
Thulo Khola HPP (Myagdi)21.3 MW
Upper Rahughat HPP (Myagdi)48.5 MW
Upper Gaddigad + Buku Kapati + Daram Khola16.15 MW
Total new capacity105.95 MW
NEA Media & Reports

NEA Publications & Auto-Publications NEA

All official NEA reports, magazines, and self-publications (स्वतःप्रकाशन). Auto-updates from nea.org.np/en/category/auto-publication.

Showing latest publications from nea.org.np · Just now
Auto Publications (स्वतःप्रकाशन)
Quarterly Self-Disclosures Auto-updated
📋
NEA publishes quarterly self-disclosures under the Right to Information Act. The latest publication (April 9, 2026) covers major activities up to Poush 2082 (December 2025).
Annual Reports & Magazines
Latest Releases nea.org.np/en/category/annual-reports
↗
● New · Apr 3, 2026
⚡
Vidyut 2082
NEA flagship annual publication
 ↗
● New · Apr 3, 2026
🏘️
NEA DCSD Magazine 2082
Distribution & Consumer Services Directorate
 ↗
● New · Apr 3, 2026
🔌
Transmission Directorate 2082
Grid, substations, and cross-border lines
 ↗
● New · Apr 3, 2026
🏭
Generation Directorate 2081/82
Plant performance, commissionings, generation data
 ↗
📊
Oct 2025
Annual Report 2024/2025 (FY 2081/82)
40th anniversary — full financials, generation, trade data
 ↗
📈
Aug 2024
Annual Report 2023/2024 (FY 2080/81)
Previous year baseline — NPR 115.5B revenue
Operational Reports
Live Operational Data
↗
⚡
Generation Directorate
Generation Operational Reports — Live daily/monthly data
 ↗
🔌
Transmission Directorate
Transmission Operational Reports — Grid status and outage data
Source: nea.org.np ↗nea.org.np ↗