Infrastructure financing eligibility structuring for a French energy operator in CIS markets. Advisory on restructuring project classification to unlock institutional and public funding for supply diversification.
Context
Infrastructure financing eligibility structuring is not a financial engineering exercise. It is an institutional design problem that determines whether a technically sound and socially necessary project can access the capital it requires or remains permanently stuck in a classification that excludes it from every available funding mechanism. This case involved a project that everyone agreed was needed, that had been technically designed and operationally scoped, and that had been rejected for financing three times because of how institutional responsibility was distributed, not because of any deficiency in the project itself.
A French energy group with operations across several European and CIS markets operated electricity distribution infrastructure in a region of a CIS country, managing the grid that connected approximately 120,000 residential and commercial consumers to the national power supply. The regional distribution network, built primarily during the Soviet period and partially upgraded in the 2000s, depended heavily on a single primary supply corridor: one high-voltage transmission line feeding into three regional transformer substations. If that corridor experienced an outage, whether from equipment failure, weather damage or upstream supply interruption, the entire region's electricity delivery was compromised. Backup capacity existed but was limited to approximately 35 percent of peak demand, sufficient to maintain hospital and emergency services but not enough to prevent widespread blackouts affecting homes, businesses and municipal infrastructure.
The French operator, which held a 15-year distribution concession for the region and employed approximately 280 local staff across operations, maintenance, customer service and grid management, had developed a reconstruction programme to diversify the supply architecture. The programme involved constructing a second supply corridor from an alternative transmission node, upgrading two existing substations, installing automated switching capability between supply sources, and reinforcing approximately 40 kilometres of medium-voltage distribution lines. The total estimated investment was EUR 14 million, with an implementation timeline of 30 months.
The operator's parent company in France, with group revenue of approximately EUR 2.4 billion and distribution operations in six countries, had evaluated the reconstruction against its internal capital allocation criteria. The project met technical and operational justification thresholds. However, at EUR 14 million it represented a commitment that the group's capital committee was unwilling to approve as a single-country, single-asset investment in a CIS market, particularly given the political and regulatory uncertainties inherent in operating under a concession that could be subject to renegotiation. The group's position was clear: the reconstruction was operationally necessary, but it would proceed only if external financing, whether from international financial institutions, European development mechanisms or national public funding programmes, covered a substantial portion of the capital requirement.
Why the Project Could Not Access Financing
The operator had submitted funding applications to three separate institutional mechanisms over a period of 18 months: an international development bank's infrastructure programme, a European bilateral energy cooperation fund, and a national government programme for critical infrastructure improvement. All three applications were rejected, and in each case the rejection was based on the same fundamental classification issue.
Under the existing contractual structure, the French operator held sole responsibility for electricity supply continuity within its concession territory. The cooperation agreements with upstream energy suppliers, the national transmission company and neighbouring distribution operators were structured as commercial procurement contracts: the operator purchased transmission capacity and wholesale electricity on commercial terms and bore full operational and financial risk for delivery to end consumers. This meant that any investment in the distribution network, including the supply diversification programme, was classified by funding institutions as a private commercial investment to improve the operator's own asset performance, not as a public infrastructure resilience measure.
The funding programmes that rejected the applications were specifically designed to support regional energy security, supply reliability and infrastructure modernisation in transition economies. The operator's project clearly served these objectives. But the institutional classification mechanisms used by the funding bodies assessed eligibility based on who bore responsibility for the outcome, not on what the outcome achieved. As long as the operator was contractually the sole party responsible for supply reliability, any investment to improve reliability was categorised as an improvement to the operator's own commercial capacity rather than a contribution to regional energy system resilience.
Why External Advisory Was Engaged
The operator's internal capabilities covered engineering design, project management, financial modelling and regulatory compliance. What they did not cover was the intersection of institutional financing logic, contractual responsibility architecture and the specific classification criteria used by international and public funding mechanisms.
The operator's legal counsel in Paris had reviewed the rejection letters and confirmed that the funding bodies had applied their eligibility criteria correctly. The problem was not a procedural error or an incomplete application. It was a structural mismatch between how the project was institutionally positioned and what the funding criteria required.
Tretiakov Consulting was engaged because the situation required someone who could work simultaneously across three domains: the operational logic of energy infrastructure investment, the contractual architecture that determined institutional classification, and the decision-making frameworks of international financing bodies and public funding programmes. The practice brought direct experience in structuring capital projects for institutional contexts where the technical merits of a project are insufficient without corresponding institutional design, a pattern that is common in CIS infrastructure investment where the gap between project quality and funding access is often a classification problem rather than a financial one.
How the Work Was Structured
The engagement began by examining not the project design or the financial model, which were technically sound, but the contractual and institutional relationships that determined how funding bodies classified the investment.
The core finding was straightforward but consequential. The existing supply agreements concentrated all reliability responsibility on a single commercial entity, the operator. Every contract in the chain, from transmission access to wholesale supply to distribution delivery, was structured bilaterally between the operator and individual counterparties. There was no institutional mechanism through which supply diversification was treated as a shared system responsibility involving multiple parties. In the eyes of every funding body, this meant the operator was investing in its own commercial resilience rather than contributing to a broader public infrastructure objective.
The advisory work developed a restructured responsibility architecture in which the supply diversification elements were repositioned from a single-operator commercial investment into a shared reliability framework involving three parties: the French operator, the national transmission company and a neighbouring regional distribution entity. The restructuring did not involve transferring ownership of any assets or changing who managed daily operations. The operator retained full operational control of the distribution network, the maintenance of all equipment and the management of consumer delivery.
What changed was the institutional positioning of the reliability improvement. The second supply corridor, the substation upgrades and the automated switching capability were reframed as shared infrastructure serving regional electricity system resilience, with coordination obligations distributed across the three participating entities. Each party assumed defined responsibilities: the operator managed construction, commissioning and ongoing operation; the transmission company assumed responsibility for capacity reservation and upstream coordination; and the neighbouring distribution entity participated in emergency interconnection protocols and load-sharing arrangements.
This required restructuring three sets of agreements. The transmission access contract was amended to include capacity reservation commitments from the transmission company that went beyond standard commercial supply terms. The interconnection agreement with the neighbouring distribution operator was formalised with mutual reliability obligations rather than the informal emergency cooperation arrangement that had existed previously. And a new coordination protocol was established among all three parties, documented as a regional reliability agreement, that created the institutional basis for funding bodies to classify the project as a multi-party system resilience measure rather than a single-operator commercial improvement.
Tretiakov Consulting designed the restructured contractual architecture, facilitated the negotiations between the three participating entities, and prepared the revised funding applications with institutional positioning that explicitly addressed the classification criteria that had caused previous rejections. The practice also supported the operator's development team through the funding body review process, including responses to due diligence questions and technical clarification requests.
What the Engagement Produced
The restructured project was submitted to two funding mechanisms simultaneously. The international development bank, which had previously rejected the application, accepted the revised submission for evaluation within six weeks of resubmission, a timeline that compared with the nine-month initial review period that had led to the original rejection. The European bilateral fund opened a preliminary assessment within the same period.
The institutional reclassification was the decisive factor. The project scope, budget, timeline and technical design were identical to the previously rejected applications. What changed was the contractual architecture that determined how the project was categorised within each funding body's eligibility framework.
The entire restructuring process, from initial diagnostic through contractual redesign, counterparty negotiation and funding resubmission, was completed in approximately four months. The operator's head of development estimated that without external advisory, the company would have continued submitting variations of the same application to different funding mechanisms, a pattern that had already consumed 18 months without result and would likely have continued until the project was either abandoned or financed entirely from internal capital at terms the group was unwilling to accept.
The operator maintained full operational control throughout the restructuring. No asset ownership was transferred, no management authority was diluted and no operational continuity was interrupted. The 280 local employees continued operating the distribution network under the same management structure. The only change visible to them was that a project they had been told might not happen began moving toward implementation.
Why This Case Matters
This engagement illustrates a pattern that is common in energy and infrastructure investment in CIS and transition economies. A project that is technically necessary, financially viable and socially beneficial cannot access available financing because the institutional classification framework does not recognise it as eligible. The project team exhausts itself producing better technical documentation, more detailed financial models and more compelling narrative descriptions, none of which address the actual barrier: who bears responsibility and how that responsibility is structured in the contractual architecture.
The advisory value in this case was not technical expertise in energy distribution and not financial modelling capability. It was the ability to read the institutional logic that funding bodies apply, identify where the project's contractual structure created a classification mismatch, and redesign that structure so that the same project, serving the same purpose with the same design, became eligible under the same criteria that had previously excluded it. The barrier was not the project. The barrier was the institutional framing. Once the framing was corrected, the financing path opened.
