Bottlenecks in Nepal's Regional Energy Trade and a Suitable Cross-Border Power Trading Framework

1. Context

Nepal's installed capacity has crossed 3,000 MW (with NEA and IPP combined), and in the wet season of FY 2080/81 the country exported surplus power to India through the Dhalkebar–Muzaffarpur and other cross-border links. Nepal has also begun tripartite export (Nepal–India–Bangladesh) via the 400 kV Dhalkebar–Muzaffarpur–Bheramara corridor. However, the transition from "seasonal surplus exporter" to a "reliable regional market participant" is constrained by several structural, regulatory, technical and commercial bottlenecks.

2. Bottlenecks in Regional Energy Trade

(a) Physical / Transmission Bottlenecks

• Limited cross-border interconnection capacity. Existing links (Dhalkebar–Muzaffarpur 400 kV, Kusaha–Kataiya 132 kV, Mahendranagar–Tanakpur 132 kV, etc.) are inadequate for large-scale export; internal transmission (e.g., 400 kV Butwal–Gorakhpur, Inaruwa–Purnia) is still under construction.
• Weak domestic grid. Congestion in the East–West and Kali Gandaki corridors restricts evacuation of power from generation clusters to border points.
• Seasonal and diurnal mismatch. Nepal has surplus in wet season/monsoon nights but deficit in dry season and evening peaks, limiting firm, round-the-year export commitments.

(b) Regulatory and Policy Bottlenecks

• Absence of a dedicated cross-border trading law/regulation. The Electricity Act 2049 and Electricity Regulatory Commission Act 2074 do not clearly provide for third-party/cross-border trading by IPPs.
• Single-buyer legacy. NEA has historically been the sole buyer/exporter; IPPs lack direct market access and must route through NEA or Indian trading licensees.
• Guidelines issued by MoEWRI (2081) on cross-border trade are recent and still evolving; clarity on licensing, eligibility and revenue sharing is limited.
• No independent system operator (ISO). NEA performs generation, transmission, system operation and trading — a conflict of interest that hampers transparent scheduling and open access.

(c) Market Access and Commercial Bottlenecks

• Dependence on the Indian market only. Access to Bangladesh, Bhutan and the wider BIMSTEC/SARRC market is through India, requiring Indian regulatory consent (CERC/CEA) and tripartite agreements.
• Competitive pricing pressure. Indian power exchanges (IEX, PXIL) often clear at low prices during wet season, reducing Nepal's export realisation.
• Payment security and currency risk. Cross-border transactions are in Indian Rupees/USD; payment security mechanisms (LC, escrow) are not fully institutionalised.
• Limited participation of IPPs. IPPs face barriers in obtaining export licences, transmission access and bilateral contracts.

(d) Technical and Grid Code Bottlenecks

• Non-harmonised grid codes. Nepal's grid code (frequency 50 Hz ± 3%, voltage limits) differs in detail from India's IEGC and Bangladesh's grid code, complicating scheduling and despatch.
• Weak SCADA/telemetry and communication links between load despatch centres (NEA LDC and POSOCO/Grid-India).
• Inadequate reactive power support and protection coordination at border substations.
• Limited forecasting capability for hydro generation (dependent on rainfall) and demand.

(e) Dispute Resolution and Institutional Bottlenecks

• No dedicated regional dispute settlement body. Disputes are settled through bilateral negotiation or Indian regulatory authorities, disadvantaging Nepal.
• Weak contract enforcement and arbitration framework in cross-border PPAs.
• Institutional capacity gaps in NEA, ERC and MoEWRI for market operations, settlement and regulation.

3. Recommended Cross-Border Power Trading Framework

A phased, rules-based framework with the following pillars is advised:

3.1 Market Access

• Enact a Cross-Border Electricity Trade Act/Regulation empowering ERC to license exporters, traders and IPPs for cross-border trade.
• Allow IPPs direct market access through:
  • Bilateral contracts with Indian/Bangladeshi utilities or traders;
  • Participation in Indian power exchanges (IEX/PXIL) via licensed Indian trading licensees;
  • Tripartite arrangements (Nepal–India–Bangladesh) with a nodal agency.
• Adopt a "regulated open access" model on the domestic grid so IPPs can wheel power to border points on payment of transmission charges.
• Establish a single-window clearance (MoEWRI/ERC/NEA) for export licences, transmission access and cross-border approvals.
• Unbundle NEA (at least functionally) into Generation, Transmission/System Operation and Trading arms to remove conflict of interest and provide non-discriminatory access.

3.2 Scheduling and Despatch

• Set up a Cross-Border Power Trading Desk within NEA's LDC (or a separate Market Operation entity) for:
  • Day-ahead and real-time scheduling with Grid-India/POSOCO and Bangladesh's NLDC;
  • Gate closure, nomination, revision and settlement procedures;
  • Scheduling of IPP exports through a transparent merit-order/contract-based mechanism.
• Adopt standard scheduling timelines aligned with the Indian Electricity Grid Code (IEGC): day-ahead (by 10:00 hrs), real-time (15-min blocks), deviation settlement.
• Introduce a Deviation Settlement Mechanism (DSM) with frequency-linked charges to maintain grid discipline.
• Use hydro-thermal coordination and reservoir scheduling to firm up dry-season export commitments.
• Deploy advanced forecasting (rainfall, inflow, demand) and SCADA/EMS for accurate scheduling.

3.3 Dispute Resolution

• Adopt a three-tier dispute resolution mechanism:
  1. Negotiation/conciliation between the parties (30–60 days);
  2. Mediation by a joint technical committee (NEA–counterpart utility–regulators);
  3. Arbitration under UNCITRAL or ICC rules, with seat in a neutral country (e.g., Singapore/Kathmandu) and enforcement under the New York Convention.
• Include a governing law and jurisdiction clause in all cross-border PPAs/trading agreements.
• Establish a Joint Cross-Border Coordination Committee (Nepal–India–Bangladesh) for operational and commercial disputes.
• Strengthen ERC's dispute settlement and regulatory capacity for domestic disputes involving IPPs.

3.4 Harmonisation of Grid Codes

• Harmonise Nepal's Grid Code with IEGC (India) and Bangladesh Grid Code on:
  • Frequency band (49.5–50.5 Hz), voltage limits, reactive power range;
  • Protection, fault-ride-through and islanding requirements;
  • Scheduling, despatch and DSM provisions;
  • Communication protocols (IEC 60870-5-101/104, ICCP/TASE.2).
• Adopt common metering and settlement standards (interface meters at border substations, ABT/availability-based tariff).
• Synchronise LDCs through dedicated fibre/OPGW communication links and joint system studies (load flow, stability, short-circuit).
• Align cybersecurity and data exchange standards for cross-border telemetry.
• Mutual recognition of grid code compliance through a Joint Technical Committee.

3.5 Supporting Measures

• Invest in cross-border transmission (Butwal–Gorakhpur 400 kV, Inaruwa–Purnia 400 kV, Dhalkebar–Sitamarhi 400 kV, and ultimately BBIN grid).
• Develop pumped-storage and storage projects (e.g., Tanahu, Budhi Gandaki) to convert seasonal surplus into firm, round-the-year supply.
• Build institutional capacity in NEA, ERC and MoEWRI for market design, regulation and settlement.
• Diversify markets beyond India — Bangladesh, Bhutan, Myanmar and eventually the BIMSTEC/SARRC grid.
• Strengthen payment security through LCs, escrow accounts and sovereign guarantees.

4. Conclusion

Nepal's emergence as a net exporter is a strategic opportunity, but it is constrained by inadequate transmission, a single-buyer legacy, weak market access for IPPs, non-harmonised grid codes, and the absence of a robust dispute resolution mechanism. A phased framework — anchored on a dedicated cross-border trade law, functional unbundling of NEA, regulated open access for IPPs, harmonised grid codes with India and Bangladesh, a transparent scheduling/DSM mechanism, and a three-tier dispute resolution system — will enable Nepal to move from seasonal surplus export to a reliable, competitive and sustainable participant in the regional electricity market.