🇩🇪Germany

Netzengpässe und Redispatch-Kosten durch Nord-Süd-Ungleichgewicht

2 verified sources

Definition

Transmission bottlenecks between North (renewable assets) and South (industrial clusters) force grid operators into expensive redispatch and countertrading operations. The current regulatory framework lacks transparent mechanisms to recover these costs, creating hidden financial leakage.

Key Findings

  • Financial Impact: €300–500 million annually (industry-estimated redispatch and countertrading costs); typical regional impact: €2–5 million per TSO per year
  • Frequency: Continuous (daily real-time balancing)
  • Root Cause: Lack of functioning capacity market and price floor mechanisms under EnWG; absence of reliable legal framework for revenue adequacy during low-price periods; spatial mismatch between generation (North) and demand (South)

Why This Matters

This pain point represents a significant opportunity for B2B solutions targeting Electric Power Transmission, Control, and Distribution.

Affected Stakeholders

TSO Finance Directors, Grid Operations Managers, Regulatory Compliance Officers

Deep Analysis (Premium)

Financial Impact

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Current Workarounds

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Methodology & Sources

Data collected via OSINT from regulatory filings, industry audits, and verified case studies.

Evidence Sources:

Related Business Risks

Netzanschlusskosten und Baukostenzuschüsse für Batteriespeicher

€2,000–€15,000 per BESS project (typical BKZ); €50–150 million sectoral annual loss; 15–25% project rejection rate due to connection cost unaffordability

Unsicherheit bei Tarifmechanismen und nicht-erzielte Einnahmen durch NEST-Reform

€200–400 million annually (aggregated across ~900 distribution operators); 8–15% average tariff adjustment delay per operator; 2–4% annual revenue shortfall during transition periods

Verzögerung bei Netzentgeltmethodik-Anpassungen und Bußgelder für Zweitarifgenauigkeit

€5,000–€50,000 per tariff calculation error; €100,000–€500,000 per audit finding; €5–20 million aggregate sectoral compliance penalty exposure (2025–2029); typical operator: €10,000–€200,000 annual audit remediation costs

Fehlende Investitionssicherheit durch Regulatorische Unsicherheit bei Wasserstoff-Ready-Kraftwerken

€500 million–€2 billion in deferred sectoral investment (2025–2026); typical project delay: 12–18 months; financial carrying cost: 4–6% annually = €20–120 million opportunity cost per year

NIS2-Bußgelder und Betriebsunterbrechungen durch mangelnde Incident Response

LOGIC-estimated: €10,000–€50,000+ per incident (typical DACH regulatory penalties); Operational risk: Potential grid outages affecting 100,000+ households (revenue impact unquantified).

Manuelle Feasibility-Studien und hohe Bearbeitungskosten

Estimated €50-150K per feasibility study × ~6,000 non-approved annual requests = €300-900M annual waste; TSO administrative overhead estimated €100-250M/year; €15-40K per TSO employee per month in overtime during peak submission periods

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