Distribution System Operator

A distribution system operator (DSO; Swedish: distributionsnätsföretag) is the entity responsible for operating, maintaining, and developing the electricity distribution grid within a concession area. DSOs deliver electricity from the high-voltage transmission system to end consumers via medium-voltage and low-voltage networks. They are natural monopolies, regulated by a national authority — Ei in Sweden.

DSOs are the key actors for distribution-level Flexibility — they procure local flexibility services, maintain the grid connection infrastructure for distributed energy resources, and issue network development plans that quantify future capacity needs.

Core responsibilities

1. Grid operation — maintaining safe, reliable supply within the concession area; monitoring voltage, managing faults, coordinating maintenance windows
2. Connection — connecting new generation, consumption, and storage installations on objective, non-discriminatory, and reasonable terms (ellagen 4 kap. 1 §); includes issuing nätanslutningsavtal and potentially flexible connection agreements
3. Power transfer — transporting electricity for others’ account through the distribution network (nätverksamhet), which requires a nätkoncession (grid licence) from Ei
4. Metering — operating smart metering infrastructure; in Sweden, DSOs own and operate the meters at all delivery points
5. Balance responsibility facilitation — DSO grids are the physical substrate for all BRP portfolio management; DSOs provide real-time and historical data to facilitate balancing
6. Flexibility procurement — DSOs must assess whether flexibility services can substitute for or defer network investment (Directive Art. 32(1)); if market-based options are available and cost-effective, procurement is the default
7. Network development planning — biennial DNDP obligation: develop, consult, publish, and submit to Ei every two years, covering planned investments and medium-to-long-term flexibility needs (Ellag 3 kap. 16 §; EIFS 2024:1)
8. Data exchange — providing data on grid topology, capacity, and connection points to the national FIS (NC DR), other system operators, and regulators

EU regulatory framework

The Clean Energy Package defines the DSO’s role in detail:

• Directive Art. 32(1): DSOs must procure flexibility services through market-based procedures unless the regulator finds this uneconomic or would cause severe market distortions. NRA may grant derogation from the market-based default. This is the statutory foundation of EU DSO flexibility procurement obligations.
• Directive Art. 32(3): Biennial DNDP obligation — must include flexibility service needs and planned investments for the next 5–10 years.
• Directive Art. 32(4): DSOs must be neutral market facilitators — they cannot favour any particular technology or solution; they must enable equal participation by all market actors.
• Directive Art. 36: DSOs are prohibited from owning, developing, managing, or operating energy storage. Exceptions for fully integrated network components or where no third-party operator exists after a competitive tender (implemented in Sweden via ellagen 3 kap. 39–40 §§ and Förordning (2022:585) §§ 18–22; from 2027-01-01 the storage dispensation rules are 4 kap. 1–5 § of the elsystemförordning, with the ban itself in 4 kap. 6 § elmarknadslagen — Source - Elsystemförordning (2026-1522)).
• Regulation Art. 13: Redispatching (including DSO-level congestion management actions) must be market-based as far as possible.
• Network Code on Demand Response: Will formalize DSO obligations around local services markets, standardized product specifications, flexibility register participation, TSO-DSO coordination, and DNDP content.

Unbundling: DSOs with ≥100,000 customers must be legally and functionally separated from generation and retail activities (ellagen 3 kap. 21–29 §§). All DSOs must maintain accounting separation.

Neutral facilitator principle: A DSO must not use its position as grid operator to advantage particular market participants — it cannot condition grid access on using DSO-affiliated services, and must allow all qualified service providers to participate in local flexibility procurement on equal terms.

Swedish DSO landscape

For the full sector landscape — ownership forms, profitability, koncernbidrag, investment levels, and tariff trends — see the dedicated overview page Swedish DSO Landscape.

Sweden has 168 elnätsföretag (Ei R2026:05, 2025): 146 local-grid, 25 regional-grid, and 2 transmission companies, with six running both local and regional grids. (Ei PM2025:03’s first-round DNDP synthesis gives the customer-tier breakdown below.) Companies hold a nätkoncession för område (area concession) or nätkoncession för linje (line concession). The area-concession voltage ceiling has by practice and förarbeten been 110 kV, with higher-voltage lines normally requiring a line concession — but in a 2026-06-22 decision Ei granted E.ON Energidistribution an area concession at 82–145 kV in the Malmö region, the first to exceed 110 kV, citing special circumstances (delimited metropolitan area, developed land, cables only) and faster/cheaper expansion than per-line prövning. (Source - Ei Beslut Nätkoncession 145 kV Malmö (2026)) Based on Ei PM2025:03:

The six large DSOs account for the majority of Swedish customers. Four of these span multiple bidding areas and are tracked separately in Ei’s DNDP synthesis: Vattenfall Eldistribution, E.ON Energidistribution, Ellevio, and Skellefteå Kraft Elnät. Each serves hundreds of thousands of customers. The 61 small DSOs together serve fewer customers than a single large company.

Sweden’s distribution grid extends up to 220 kV — Swedish DSOs can hold regionnät (regional grid) licences at voltages that would be TSO-operated in other countries. The boundary with Svenska kraftnät‘s transmission system is not strictly voltage-defined.

Key Swedish DSO entities in the wiki: Vattenfall Eldistribution, E.ON Energidistribution, Ellevio, Göteborg Energi Nät, CoordiNet (demonstration), Effekthandel Väst (Göteborg Energi Elnät + Mölndal Energi Elnät). For sector-wide economics and ownership, see Swedish DSO Landscape.

Swedish regulatory framework

The Swedish regulatory chain governing DSOs:

Revenue cap regulation (intäktsramsreglering): Ei regulates each DSO’s maximum revenue through four-year supervisory periods (tillsynsperioder). Current period: RP4 (2024–2027). The RP5 reform (2028–2031) will introduce TOTEX benchmarking — mandated by ellagen 5 kap. 12a § — which creates lösningsneutralitet (solution neutrality) between grid investment and flexibility procurement, removing the historical CAPEX bias. See Ei › Key positions.

Product specifications: Under Förordning §§ 10–12, DSOs must develop product specifications for flexibility services they procure, submit them to Ei for approval, and publish approved products. Ei must approve if specifications ensure genuine, non-discriminatory participation by relevant market participants.

Förhandsprövning (proposed): In February 2026, Ei submitted a formal hemställan to the government to amend ellagen 4 kap. 46–47 §§ and add § 36a to Förordning (2022:585), introducing a statutory duty for Ei to pre-approve DSO tariff methods for connection and transfer charges before they enter into force. Sweden and Finland are currently the only two EU member states where the NRA neither decides nor pre-approves DSO tariff methods (ACER 2025 report); all other EU members have some form of ex-ante control. Sweden lost an EU infringement case in 2009 (C-274/08) and extended pre-approval to revenue caps (intäktsramar), but never to the underlying tariff methodologies. Under current law Ei can only correct tariff deficiencies going forward via tillsyn — not retroactively. About 30 DSOs have introduced effektavgifter with potential design deficiencies (timing windows, level-setting) that pre-approval would catch before customer impact. If the government adopts the proposal, implementation would be a two-step process: amend ellagen/Förordning (earliest in force 1 January 2027), then Ei develops the actual approval föreskrifter — estimated at 1–2 additional years. Actual pre-approval of DSO tariff methods would therefore not begin until 2028 at the earliest. Adoption by the government is still pending as of May 2026. (Source - Ei R2026-04 Förhandsprövning Avgifter (2026))

DSO and flexibility

DSO flexibility procurement is the central focus of the NC DR, the Flexibility Market, and Swedish regulatory reform. Key dynamics:

Art. 32 obligation: Since the Clean Energy Package entered force, Swedish DSOs have been obliged to consider flexibility services as alternatives to network investment. Implementation was initially uneven — most DSOs cited lack of local markets or suppliers, applying Art. 13(3) exceptions.

Market-based default: Ei has classified Villkorade Avtal as non-market-based redispatching, meaning they are a permitted exception to the market default rather than a compliant market-based tool. DSOs using only villkorade avtal must satisfy the Art. 13(3) conditions — primarily that no market-based alternative is available or cost-effective.

Tool mix (from Ei PM2025:03, first-round DNDPs):

• ~20% of DSOs currently use flexibility services — but representing ~70% of customers
• All 6 large DSOs use flex services; only ~10% of small DSOs do
• ~15% considering creating or participating in flexibility markets
• ~40% mention villkorade avtal or bilateral agreements
• 5 companies used omdirigering (redirection) in 2023

DNDP obligation: Since December 2024, Swedish DSOs have had to submit a mandatory biennial DNDP under EIFS 2024:1; Ei reviewed 152 plans in the first round. The plans must include: MW-quantified flexibility needs per delområde on a 5–10 year horizon (§ 4.12); adequacy assessment; and consultation results. Ei published a synthesis of the first round in Ei PM2025:03 (March 2025). (Source - Ei PM2025-03 DNDP Sammanställning (2025))

DNDP and self-consumption growth: Commission Recommendation C(2026)2850, Rec 11, specifies that DSOs must account for the expected growth and impact of self-consumption and energy community operations in their grid development plans, to allow for anticipatory investments. This extends the existing quantitative flexibility need obligation to explicitly include the self-consumption side — relevant for the next DNDP cycle (2027–2036). (Source - Commission Recommendation C(2026)2850 Energy Communities)

NC DR and Sweden’s multi-DSO challenge: The forthcoming Network Code on Demand Response will require DSOs to participate in developing national Terms & Conditions for flexibility markets, registers, and products. Sweden’s 168 DSOs — predominantly small and medium-sized — present a design challenge for representative T&C development processes that Ei is actively working to address, with the process design due 12 months after NC DR entry into force. (Source - Ei NC DR Förberedelser (2025))

TSO-DSO planning cooperation structure: Svk’s Planering för ökad elanvändning (February 2025) documents the formal cooperation structure between Svenska kraftnät and the five major regional grid companies (regionnätsföretag): Vattenfall Eldistribution, Ellevio, E.ON Energidistribution, Jämtkraft Elnät, and Skellefteå Kraft Elnät. These are the only DSOs directly connected to the transmission grid and are therefore Svk’s primary DSO planning partners. Key forums:

• Nätplaneringsforum — annual strategic meeting for planning directors
• Systemforum TSO/DSO — started 2021 under the Electricity Market Regulation; handles strategic system responsibility questions; includes voltage/reactive power working group
• Nätägardialogen — Svk DG + DSO CEOs; drives the prognossamverkan initiative
• Prognossamverkan TSO/DSO — 6–8 meetings/year; joint demand forecasting with shared methods including AI-based dynamic load-type curves

Two identified improvement areas as of February 2025: (1) stronger forecast cooperation including shared scenarios and automated data exchange; (2) clarifying responsibility for capacity shortage, subtransmission, and flexibility — the last explicitly awaiting NC DR legislation before TSO/DSO responsibilities can be formalized. (Source - Svk Planering för ökad elanvändning (2025))

Svk anvisningssystem — coordination implications: Svenska kraftnät‘s April 2026 government assignment report (Dnr 2025/5008) proposes the Anvisningssystem, an allocation system for TSO-level connections using kapacitetszoner. DSOs (regional grid companies — regionnätsföretag) are central to the practical operation of this system: it is regional DSOs, not individual end customers, who apply to Svk for connection capacity. The report introduces:

• Linked applications: regional DSOs would facilitate and manage applications where production and consumption applicants want to file jointly (matchning), including transparency requirements on what profile criteria parties must meet
• Mandatory tripartite dialogue: Svk will introduce obligatory three-way dialogue between Svk, the regional grid company, and its large customer for major connection applications
• Standardized capacity principles: Svk and regional DSOs are developing principles for effective capacity allocation based on actual utilization profiles — relevant for both regional grid planning and connection queue management (Source - Svk Anslutningsprocessen Rapport (2026))

Global context (IEA, 2026). The IEA’s electrification report (IEA Special Report on Electrification) says nearly two-thirds of grid investment is in distribution networks, that distribution grids must handle higher peaks, bidirectional flows and variable EV, heat-pump and data-centre demand, and that many still lack real-time visibility, automated control and the digital capability to use demand-side flexibility. Grid investment is projected to rise from USD 450 billion (2025) to about USD 930 billion by 2035 in its High Electrification Scenario.

Truck-charging hotspots. An ICCT and Fraunhofer ISI model (ICCT and Fraunhofer ISI analysis) finds that electric-truck charging demand is highly concentrated: the top 10% of hexagons hold 60–90% of national charging energy and the most heavily loaded hexagon reaches 20–50 MW in the largest freight countries, so reinforcement would fall on the specific DSOs serving freight corridors and industrial hubs. It is a modelled projection for trucks over 12 tonnes.

Capacity calculation doctrine: faktisk belastning

The report addresses luftbokning (air booking) as a possible cause of apparent congestion in Sweden’s distribution grid — its own glossary defines this narrowly as large planning margins added because of uncertainty about existing customers’ future transmission needs, distinct from (but related to) DSOs tying allocated grid capacity to a customer’s contracted power (abonnerad effekt) rather than actual physical load (faktisk belastning).

Ei has established the faktisk belastning doctrine (reaffirmed in Ei R2024:14) that governs how DSOs must calculate available capacity for new connection applications:

A DSO must calculate the available capacity on a grid segment using the actual physical load of existing customers, including statistical diversity (sammanlagring) effects — not the sum of their contracted power capacities.

R2024:14 does not describe an AMI/smart-meter-data methodology or a documentation mandate for this; the concrete development it reports is legal: ellagen 4 kap. 2 § now puts the burden of proof on the DSO to show a capacity shortfall cannot be resolved in a socioeconomically justified way before it may refuse a connection, and Ei plans to publish guidance on those assessments during 2025.

Key legal clarification: Abonnerad effekt under EIFS 2022:1 is a cost-allocation criterion — how grid costs are divided among customers — not a right to specific physical grid capacity. A customer who has contracted a given level of power cannot legally claim that the DSO must reserve that exact amount of grid capacity for them at all times.

Asymmetric constraint: While DSOs must use faktisk belastning for capacity availability calculations (new connections, grid planning), they cannot unilaterally reduce a customer’s contracted capacity based on observed actual usage. Abonnerad effekt is a contractual right requiring customer consent or a tariff redesign process to change.

(Source - Ei R2024-14 Outnyttjad Kapacitet (2024)): Ei’s government assignment concludes that DSOs already have wide scope to use unused capacity, proposes no new rules on connection-charge refunds, and recommends implementing the earlier SOU 2023:64 proposals — the tools (faktisk belastning doctrine, forthcoming Article 6a FCA framework, TOTEX reform via RP5) are already in place or forthcoming.

Art. 31.3 — Quarterly capacity publication (Directive 2024/1711): Directive 2024/1711 adds Art. 31.3 to the revised EMD, requiring DSOs to publicly disclose available capacity for new connections within their area with high spatial resolution, updated at minimum quarterly. The disclosure must include: capacity currently under pending applications; and, critically, availability of flexible connections in congested areas — making the Art. 6a flexible connection opportunity machine-readable and public. Connection applicants must receive progress updates within 3 months of application and quarterly thereafter. DSOs with <100,000 connected customers may be exempt by national regulation. Implementing regulations had not been issued as of the Prop.’s September 2025 enactment; Ei is expected to issue föreskrifter. (Source - Promemoria Förbättrad utformning av EUs elmarknad (2025), Source - Prop. 2025-26-16 Forbattrad utformning av EUs elmarknad (2025))

What DSO means in the control room

Everything above is the regulatory and market framing of the DSO role. A separate, practitioner-level question is what the DNO→DSO transition actually changes in day-to-day control-room (driftcentral) practice — a perspective largely absent from official Ei/EU sources but argued in detail by a grid-operations practitioner’s 2026 essay.

The shift is “operator,” not the rebrand itself. Where a network operator owns, maintains, and repairs the grid, a system operator actively follows, controls, and assesses the grid while it is in operation — real-time monitoring and proactive fault anticipation, not just reacting after a fault occurs. The author is explicit that this isn’t driven by an “inevitable explosion” in electricity consumption (Swedish consumption has arguably fallen since the Barsebäck 1 closure in 1999, even as Svk’s own long-term forecasts still project future growth) but by the grid becoming more variable — more local production, batteries, EVs, direction-changing power flows — producing localized voltage and capacity problems that a purely reactive, total-energy-focused operating model misses. Most substations rarely exceed 50% loading at peak; the DSO case isn’t “every station is about to max out,” it’s that problems are local and intermittent rather than uniform.

From reactive to proactive. Traditional control-room work responds to what has already happened (a breaker trips, an alarm fires, a meter reports an outage). DSO work extends earlier — trying to understand what is about to happen, using signals that often precede a fault: temperature change, recurring earth faults, voltage variation, rising load, short interruptions, deviating meter readings. Not every fault gives warning (a dug-up cable is a dug-up cable), but many do.

ADMS’s job, distinguished from SCADA: SCADA shows what the installation is doing; an ADMS is meant to help understand what that means, by fusing the network model, SCADA, outage management, metering, customer data, fault indicators, and work-order/reserve-feed status into one coherent situational picture — reducing what an operator has to personally piece together across a dozen separate systems during a live event, rather than adding another screen. FLISR/FDIR (automated fault isolation and restoration) is the automation layer ADMS typically hosts, but it can only reconfigure around physical alternatives that actually exist — a perfect computed switching plan is moot without a real alternative feed path, which is why the author argues redundancy investment (extra feed points, remote-controlled breakers, dual transformers at high-consequence sites) is a precondition for automation paying off, not an optional extra on top of it.

Organizational model — the Kraftringen Nät example. At Kraftringen Nät, control-room operators (driftledare) rotate: two weeks on shift as duty engineer in an eight-week cycle, the other six weeks working as driftingenjörer analyzing past events, reviewing recurring alarms, and identifying where better remote control or reserve feeds are needed. The author argues this rotation is a strength — control-room experience sharpens the analysis work, and the analysis work better-prepares the next shift — and predicts the driftingenjör role becomes more important, not less, as the grid automates, since someone has to check the automation’s decisions who isn’t simultaneously running live operations. (Source - Från DNO till DSO LinkedIn Artikel (2026))

Independent corroboration: Kraftringen’s own 2027–2036 DNDP, filed the same month, makes the essay’s exact ADMS argument from the regulatory-filing side rather than the practitioner-essay side — the company names an ADMS rollout starting 2027 for precisely the reasons the essay describes in the abstract: better real-time situational awareness, more effective flexibility targeting, and more disciplined reinforcement prioritization. A practitioner argument and a primary source agreeing on the same specific claim, from the same company, in the same short window, is a stronger data point than either alone.

Digital connecting SO (NC DR concept)

The DSO Entity report (2026) describes DSOs evolving toward a role as “Digital Connecting System Operators” — the trusted operator of the digital communication layer between controllable units (CUs) and local flexibility markets, building CU-registration modules on existing infrastructure rather than building new platforms from scratch (Recommendation R8, echoed in the report’s conclusions). As aggregation, VPPs, and cross-DSO service provision become common, the entity operating the physical connection point may not be the same as the entity operating the digital communication and control interface. This is a general framing for the DSO’s evolving role, not a standalone numbered critical action in the report. (Source - DSO Entity Distributed Flexibility Practices (2026))

Relationship to other wiki concepts

• Transmission System Operator: the TSO operates the high-voltage transmission grid; DSOs connect to it via gränspunkter; TSO-DSO coordination is a central design problem in the Network Code on Demand Response
• Ei: regulatory authority; sets revenue caps, approves product specifications, receives DNDPs, supervises compliance, and will design the NC DR T&C process
• Distribution Network Development Plan: the DSO’s primary strategic planning document; biennial obligation under Ellag 3 kap. 16 §
• Flexibility Market: DSO-operated or DSO-facilitated markets for local congestion management
• Villkorade Avtal: conditional connection agreements; the most widely used DSO flexibility tool in Sweden
• Aggregation: DSOs interact with aggregators as service providers in local markets and as holders of connection points for pooled resources
• Network Code on Demand Response: the EU regulation that will most significantly reshape DSO obligations from 2026 onwards
• Natural Monopoly: the economic basis for DSO regulation and the neutral facilitator principle
• Grid Capacity Utilization: freeing 20–40% more capacity in existing grids via technical/operative/contractual measures; EIFS 2023:6 defines effektivt nätutnyttjande as “low network losses and even power” (3 kap. §11); also covers the sector’s declining utilization-rate trend
• Load Forecasting: AI/data-driven demand forecasting capability gap across Swedish DSOs (PREDATOR/DESGRID)
• Digitalization and Smart Grid: substation digitalization baseline and the broader smart-grid orientation hub
• Elmarknadshubb: the DHV/FIS centralization of DSO administrative tasks (settlement, data distribution)
• SO GL Art. 182 agreement (draft in remiss to 26 October 2026): a voluntary agreement with Svk under which a signing DSO gets a right to run grid prequalification of balancing resources of at least 0.5 MW in its area (decision within 4 working weeks, with a missed deadline counted as approval) and to set temporary limits of up to two days, notified by 14:00 on D-2. (Source - Svk Energiföretagen SO GL Art 182 Avtal (2026))

EU DSO Entity

The EU DSO Entity (established under Regulation (EU) 2019/943, Art. 55) is the EU-level representative body of DSOs, co-authoring network codes alongside ENTSO-E. As of 2024 it represents 830+ DSOs serving 250 million+ customers across 27 EU member states. (Source - EU DSO Entity Technical Vision (2024))

The Entity’s 2024 Technical Vision identifies four core development areas for DSOs:

Digitalization underlies all four areas: the Technical Vision advocates for a Decentralized Data Space — interoperable, privacy-compliant data infrastructure managed by DSOs as primary data custodians for distribution-level customer and system data.

The Technical Vision concludes with a call to cooperation with ENTSO-E, the European Commission, ACER, and all network users — framing DSOs as co-architects of the energy transition, not just passive infrastructure operators.

Position on the July 2026 tariff proposal. In its reaction to the Commission’s proposal COM(2026) 600 the Entity backs recognition of anticipatory investment and a voluntary grid-data framework it would run with ENTSO-E, but asks for investment and resilience to be cost-allowance objectives alongside cost-efficiency, and opposes delegated-act tariff harmonisation, mandatory DSO benchmarking, the priority for non-wire solutions in DNDPs and the connection-prioritisation article (DSO Entity’s reaction).

AI-driven load forecasting and data centralization

Two structural gaps affecting DSOs are treated in depth elsewhere: the sector’s largely absent internal AI/data-driven load forecasting capability (PREDATOR/DESGRID findings) is covered in Load Forecasting › AI-driven load forecasting — sector capability gap, and the planned centralization of DSO administrative tasks (grid settlement, data distribution, delivery structure management) into the national data hub is covered in Elmarknadshubb.

Connection process — Ei ställningstaganden and EU guidance

In 2025 Ei published four ställningstaganden (Ei2025:02–05) clarifying DSO obligations in the connection process, and the December 2025 European Grids Package added non-binding EU guidance (C/2025/8473) on timely connections. Headline points:

• Ei2025:02 — flexibility as a connection-delay prerequisite: when a customer challenges a long connection time, Ei verifies the DSO investigated whether flexible resources could free capacity; capacity shortage is not valid grounds for refusal if flexibility can address it without grid extension. Endorses mognadsgrad (maturity grade) as a queue tool.
• Ei2025:03 — anticipatory investment as a legal obligation (from 3 kap. 1 §, 4 kap. 1 §, 4 kap. 5 § ellagen), with 5 kap. 7 § as the cost-recovery skälighetsbedömning escape valve; the DNDP is the planning vehicle.
• Ei2025:04 — external financing of grid components is permitted; assets enter the capital base with a rådighet indicator (ägd / hyrd / partial) only when operated by the DSO.
• Ei2025:05 — referral down the grid hierarchy: a DSO/TSO may refer an application to a lower level for special reasons, but cannot require applicants to start low; Svenska kraftnät can be obligated to connect a customer who skipped the regional grid (4 kap. 1 § anslutningsplikt).
• EU guidance (C/2025/8473): ≥16 of 27 member states face connection queues; recommends first-ready-first-served, transparent maturity criteria, milestone penalties, locational signals, and Art. 6a flexible connections — the same problem set Sweden addresses via Ei2025:02 and Svk’s Anvisningssystem.

These four layers — faktisk belastning doctrine, the Ei2025:02–05 ställningstaganden, Svk’s anvisningssystem/kapacitetszoner, and EU Art. 6a/31.3 — are analysed together as a system in DSO Connection Queue Reform — The Swedish Policy Response. (Source - Ei Ställningstaganden Anslutningsprocessen (Ei2025-02 till 05), Source - Svk Anslutningsprocessen Rapport (2026))

Grid utilization trends (declining utnyttjningsgrad/medellastfaktor, Ei R2026:02) and the substation digitalization baseline (Ei SGI 2024) are covered on Grid Capacity Utilization › Grid utilization trends — Ei R2026:02 and Digitalization and Smart Grid › Substation digitalization baseline — Ei SGI 2024 respectively.

Data gaps

• How small DSOs (<10,000 customers) are handling DNDP compliance in practice — Ei’s tillsyn findings
• European DSO governance models studied by Ei for NC DR T&C process design (early 2026 study)
• Whether NC DR T&C process will give small DSOs meaningful representation vs being dominated by the six large companies
• Independent verification of the claim (from a practitioner essay, not an official statistic) that Swedish electricity consumption has declined since the Barsebäck 1 closure in 1999 — worth checking against Energimyndigheten/Svk historical consumption series if it becomes load-bearing elsewhere