Glossary

Canonical terminology for the Flex Wiki. NC DR terms are preferred where the Network Code on Demand Response defines them — these will become binding EU-wide definitions. Swedish terms are included where they are standard usage.

A

Abonnemangsväxling (Swedish) “Subscription switching” — a coordination mechanism used in sthlmflex that enabled flexibility resources in any of the three Stockholm regional DSO areas to be used by any buying DSO. When a regional DSO purchased flexibility from a resource in another DSO’s network area, the resource’s DSO received a reduced subscription from Svenska kraftnät, while the buying DSO’s subscription was raised correspondingly — on an hour-by-hour basis. Financial settlements were handled by the market operator (NODES); subscription management was handled by Svenska kraftnät. Required specific bilateral and three-party agreements between Svk and the participating regionnätsbolag. Not applicable to E.ON Energidistribution’s lokalnät participation in sthlmflex. (Source - sthlmflex säsong 3 (2022-2023))

Acesso com restrições (Portuguese) “Restricted access” — Portugal’s structural equivalent of Swedish villkorade avtal. A distribution network connection where the customer or producer is granted access at a capacity level that the DSO (E-Redes) may curtail when the network is constrained. ERSE’s 2025 opinion on PDIRD-E 2024 explicitly recommends E-Redes actively publish available-but-not-firm capacity and offer restricted access — particularly to storage operators who can develop flexible business models around it. (Source - ERSE Parecer PDIRD-E 2024)

Active customer Final customer or group of customers who consume, store, or sell self-generated electricity, or participate in Flexibility schemes or energy communities. Amended by Directive 2024/1711 to explicitly include customers sharing electricity within other premises — covering energy sharing participants. (Directive 2019/944, Art. 2(8) as amended by Directive 2024/1711)

Adaptiv planering (Swedish) — adaptive planning A network-planning approach for high uncertainty: combine reversible measures (e.g. flexibility procurement) with irreversible ones (e.g. grid reinforcement), staging and revising decisions as the future clarifies, to limit the risk of over- or under-investment. Proposed by Energiforsk’s holistic network-development study as the frame for choosing a balanced mix of capacity measures, since no general rule of thumb settles flexibility-vs-reinforcement. See Grid Capacity Utilization › Choosing the measure mix — a decision process, DSO Flexibility Valuation — Methods and Swedish Evidence. (Source - Energiforsk 2026-1192 Holistisk Nätutvecklingsstrategi (2026))

ADMS — Advanced Distribution Management System The control-room system layer that fuses network model, SCADA, outage management, metering, customer data, fault indicators, and work-order/reserve-feed status into one situational picture — distinct from SCADA, which shows what the installation is doing but not what that means. A well-designed ADMS is meant to reduce what a control-room operator has to look at (by synthesizing signals into a coherent picture), not add another screen to monitor. See FLISR for the automated-reconfiguration logic ADMS typically hosts. (Source - Från DNO till DSO LinkedIn Artikel (2026))

aFRR — Automatic Frequency Restoration Reserve Balancing product activated automatically within ~30 seconds to minutes to restore frequency to 50 Hz after FCR activation. Bidirectional. See Balancing Markets.

Aktiv systemdrift (Swedish) — active system operation Operating the grid dynamically and in real time — reconfiguring network paths, steering loads/flows, and applying risk-based loading rules — to turn technical capacity potential into allocated capacity, rather than running statically against conservative fixed limits. One of the three capacity-release measure families (technical / operative / contractual); the operative one. Demonstrated in the UK Flexible Plug and Play pilot (active system management within flexible agreements). Requires more metering data, modernised forecasts, and a changed view of margins and risk. (Source - Energiforsk 2026-1190 Kapacitet för Tillväxt (2026))

Aktivering (Swedish) — activation The flexibility provider’s execution of a called-off bid — the actual delivery, once the grid owner has made an avrop (call-off). Distinguishes the act of delivering flexibility from submitting a bid or holding availability. (Source - Energiföretagen Förteckning Standardiserade Marknadsprodukter (2025))

Aggregation / aggregator Combining multiple customer loads or generated electricity for sale, purchase, or auction in electricity markets. An independent aggregator operates without being affiliated with the customer’s supplier and cannot be required to obtain supplier consent. See Aggregation. (Directive Art. 2(18), Art. 13)

Anslutningsavgift (Swedish) — connection charge/fee The one-time fee a Swedish grid company charges to connect a facility to the electricity grid. From 1 January 2027, governed nationwide by EIFS 2026:10: the default principle is a shallow (grund) charge — the customer pays only customer-specific costs up to the nearest feeding/receiving transformer station or network part, with overlying-grid costs socialised via transmission tariffs — subject to a deeper-charge exception for särskilda skäl (special reasons), and mandatory schablon (standard) pricing by fågelvägsavstånd for facilities ≤25 A. See Anslutningsavgift (distinct from Anslutningsplikt, the connection obligation). (Source - EIFS 2026-10 Anslutningsavgifter för Elektriska Anläggningar (2026))

Anticipatory investments EC formal definition (June 2025): “investments into grid infrastructure assets that proactively address network development needs beyond the ones corresponding to reinforcements relating to currently existing grid connection requests, that are justified in network development plans.” (Source - EC Study Distribution Grid NDP Tariffs and Connections 2025) — grid investments sized for expected future needs rather than only current confirmed connection requests. Introduced as a concept in the revised EU Grid Action Plan and the amended Electricity Market Directive. The principle: distribution grids should not become bottlenecks in the energy transition; earlier investment can avoid costlier later upgrades and accelerate RES connection. DNDPs should flag which projects are “anticipatory” — enabling market participants to see where future grid capacity will be available ahead of actual requests. Requires a regulatory incentive framework that does not penalize anticipatory investment, which connects to the TOTEX/lösningsneutralitet reform at Ei. (Source - DSO Entity DNDP Good Practices (2024))

Anvisade elavtal (Swedish: assigned electricity contracts) The legacy Swedish arrangement whereby a customer without an active supply contract (e.g. after moving) is automatically assigned a supplier by the DSO — typically one in the same corporate group, and 30–50% more expensive than an actively chosen contract. Abolished by the new Elmarknadslag (Prop. 2025/26:240, in force for this part 1 July 2027) and replaced by the sistahandsleverantör model. (Source - Prop. 2025-26-240 Nya lagar om elsystemet (2026))

API — Application Programming Interface A defined interface letting one system request or exchange data with another without needing to know its internals. In a Swedish flexibility-market context: how a DSO’s own systems, NODES, SWITCH, or a data-hub proposal actually connect to move metering and forecast data between organisations, as distinct from a one-off manual export. NODES and SWITCH both publish their own API specifications; a DSO shaping its own data export against one of them avoids a second integration project later.

Availability contract (fast bid agreement) A capacity-based payment to a flexibility service provider for being available to deliver flexibility, regardless of whether the DSO actually activates the resource. A key finding from CoordiNet: energy-only payment is insufficient for FSPs to make the investment in flexibility provision given the high variability (3×) in activation frequency between warm and cold winters. Availability contracts provide a predictable revenue floor that makes the FSP business case viable in thin, weather-dependent markets. Introduced in CoordiNet Skåne from winter 2020/2021, Uppland from 2021/2022. (Source - CoordiNet D4.7.2 Swedish Demonstration (2022))

Avrop (Swedish) — call-off The grid owner’s order for flexibility — both an availability/capacity product and an energy-activation product can be called off (avropas). Distinct from aktivering (activation): an avrop is the order, aktivering is the provider carrying it out. (Source - Energiföretagen Förteckning Standardiserade Marknadsprodukter (2025))

B

Balance Responsible Party (BRP) Market participant financially responsible for imbalances between scheduled and actual electricity injection/withdrawal. Aggregator activations may trigger energy transfer between BRP portfolios. In the Swedish balancing market, each delivery point belongs to exactly one BRP; when an aggregator activates a resource, the resulting energy shift must be settled between BRPs. (Regulation Art. 5; Source - Svk Artikel 18 Villkor Balansering (2024))

Balance Service Provider (BSP) / leverantör av balanstjänster Entity providing balancing services (FCR, aFRR, mFRR) to a TSO. A BSP may aggregate units from multiple BRP portfolios — this is the mechanism intended to enable cross-BRP aggregation in balancing markets. Defined in Source - EB GL (Regulation 2017-2195) Art. 16; national terms under Art. 18 must include aggregation rules (Art. 18.5.c). In Sweden, Svenska kraftnät‘s consolidated 2024 terms (reference 2024/2011) define BSP objects (FCR-objekt, aFRR-objekt, mFRR-objekt) that may span multiple BRPs, but bid submission rules (Arts. 10a/10b/11a/11b) require same-BSP per bid — creating the “paper construction” where cross-BRP aggregation is defined but not operationally available. Full functional implementation deferred to 2028. See Aggregation › The “paper construction” — objects vs. bids.

Balanspunkt (Swedish) — balance point NordREG’s term for the network node at which an aggregator’s portfolio is measured and settled with the TSO balancing system. Distinguished from uttagspunkt (withdrawal point — the individual customer’s metering point). Under NordREG’s two-model framework for independent aggregation: Model 1 requires each aggregator resource to sit in its own BRP portfolio (solved with multiple BRPs); Model 2 uses a single BRP with a compensation mechanism between BRPs for imbalance effects. The balanspunkt concept underpins the compensation mechanism design — the aggregator’s deviation from baseline at the portfolio level triggers financial settlement at the balanspunkt. Sweden’s implementation uses the compensation mechanism model. See Aggregation. (Source - Ei R2021-03 Oberoende Aggregatorer)

Balancing markets Markets through which TSOs procure reserves and activate energy to maintain real-time generation-consumption balance. Nordic products: FCR-N, FCR-D, aFRR, mFRR. (Regulation Art. 6)

Baseline Calculator (IA DR role) The party responsible for calculating baselines for Controllable Units under NC DR Title II baseline methodology. One of the new functional roles introduced by the IA DR (Implementing Act on Demand Response) that are not present in the main NC DR or IR 2023/1162. The Baseline Calculator works with the Baseline Provider to determine the counterfactual consumption or generation that serves as the reference for flexibility quantification.

Baseline methodology Method for determining what a resource’s consumption or generation would have been without flexibility activation. Essential for verifying delivery and settlement. Contested in the NC DR — debate over whether smart meters suffice or dedicated metering is needed.

BeFlexible EU Horizon Europe research and innovation project (2022–2026, 20 partners, €10.5M budget) that validated flexibility solutions across three regional demonstrations — South-Mid Europe (Italy), North Europe (Sweden), and South-West Europe (Spain/France). The Swedish demo, led by E.ON, developed and validated SWITCH and its local flexibility markets; project outputs are cited throughout the wiki, primarily via the two Swedish demo deliverables (D5.1, D5.2) and a project-wide summary booklet. See E.ON Energidistribution, CoordiNet (the earlier project SWITCH originally grew out of). (Source - BeFlexible Technology Booklet (2026))

Berättigad part (Swedish — “entitled party”; also called energitjänsteföretag on Edielportalen) A recognized Swedish electricity market actor type holding the right to access a consumer’s metering data for the purpose of providing energy services — including flexibility, demand response, and automated optimization. Operational from 1 June 2025 (EU legal basis: Directive 2019/944 Art. 23, applicable from 5 January 2025; Swedish national rules in Mätföreskriften + Ediel-anvisning from 1 June 2025). Process: the berättigad part signs an Ediel-avtal with Svenska kraftnät and bilateral agreements with each DSO where its customers are located; sends PRODAT Z13 to request data access; consumer approves via Mina sidor within 21 days; DSO confirms via Z14 and begins delivering quarterly (15-minute resolution) meter data. Before this mechanism, data access required case-by-case power-of-attorney arrangements — the berättigad part mechanism replaces this with a standardized process. Historical data (up to 3 years) can be requested alongside ongoing access. DSOs charge per-transaction fees (rates vary and must be published). See Berättigad part. (Source - Svensk Elmarknadshandbok 26A (2026))

Bidding zone (preferred NC DR term) / bidding area (Swedish usage) Geographic area within which a single electricity price applies. Sweden has four: SE1–SE4. Structural congestion between zones is reflected in price differences. See Bidding Areas. (Regulation Art. 2(65), Art. 14)

Budväljare (Swedish) — bid selector The Nordic algorithm that selects which mFRR balancing-energy bids to activate to cover each TSO’s need every 15-minute settlement period. Svk operates both a Nordic budväljare (shared) and a local one. From 22 June 2026 the Nordic selector uses elastisk efterfrågan in place of the toleransband. See Nordic Balancing Model, Balancing Markets. (Source - Svk Elastisk Efterfrågan mFRR (2026))

C

CAES — Compressed Air Energy Storage Hours-timescale storage technology with limited deployment. See Energy Storage.

CAPEX bias Structural incentive in the Swedish revenue cap regulation (intäktsramsregleringen) that makes grid investment more attractive to DSOs than flexibility procurement, because capital investments earn regulated return while flexibility is treated as operating expenditure subject to efficiency requirements. Identified by Ei as a barrier to flexibility adoption (Source - Ei Flexibility in Distribution Grids (2023)). Being addressed from 2028 through the TOTEX reform introducing lösningsneutralitet — see Source - Ei Inriktning intäktsramar 2028-2031 (2025).

Cost cascading The allocation of network costs from higher to lower voltage levels, so a network user pays for the voltage level they connect to plus the higher-level networks feeding it. Applied top-down in all EU member states, and the reason distribution charges dominate the bill (~EUR 60 bn against ~EUR 20 bn transmission across the EU in 2023). The Commission notes the model assumes downward flow from central generation, which fits poorly now that 60–90% of new connections are distribution-level and 70% of renewables are expected there by 2030; NRAs are invited to reconsider how they apply it and to coordinate on new approaches. See Distribution System Operator. (Source - C(2026)126 Future Proof Network Charges Guidelines)

Cascade model (kaskadmodell) Market integration approach where bids not cleared on a local Flexibility Market are forwarded to another market (e.g., Svk’s mFRR market). Tested on CoordiNet and sthlmflex in Sweden. Enables value stacking across markets. (Source - Ei Flexibility in Distribution Grids (2023))

CEP — Clean Energy Package Set of eight EU legislative acts (2018–2019) rewriting rules for European electricity markets. The two most relevant to flexibility: Directive 2019/944 and Regulation 2019/943. See Clean Energy Package.

Citizen energy community Legal entity controlled by members located near renewable energy projects, whose primary purpose is to provide environmental, economic, or social community benefits rather than financial profits. Can collectively participate in Flexibility Markets. (Directive Art. 16)

CNEC — Critical Network Element and Contingency A specific combination of a network element (transmission line, transformer, or corridor) and a contingency scenario (N-0 normal state, or N-1 after a defined fault) that is monitored in Flow-Based Capacity Calculation. The flow on each CNEC must not exceed its thermal limit (Fmax). The RAM (remaining available margin) on a CNEC is the share of its capacity left for cross-zonal trade after subtracting reliability margins, already allocated flows, and flows in a zero-net-position scenario. CNECs whose maximum zone-to-zone PTDF (Power Transfer Distribution Factor) falls at or below 5% are excluded from the flow-based domain as not significantly influenced by cross-zonal trade (CACM Art. 29.3(b)). See also: CDC, RAM, PTDF, Flow-Based Capacity Calculation. (Source - Nordic CCM Third Amendment Package (2026))

CONDON — Coordination of the Nordic transmission system operators. The informal coordinating body of the four Nordic TSOs: Fingrid (Finland), Energinet (Denmark), Statnett (Norway), and Svenska kraftnät (Sweden). CONDON publishes joint positions, coordinates technical standards, and aligns requirements for connected technologies across the Nordic synchronous area. Notable output: the November 2025 joint position on grid-forming converter requirements — the first pan-Nordic GFM specification framework. (Source - CONDON Nordic Position on Grid-Forming (2025))

Critical peak pricing (CPP) A flexible retail contract type where the electricity price is raised substantially during periods of excessive demand or tight supply, to incentivise reduction when the system is stressed. Commercial CPP offers are ordinary retail products and coexist with the peak-shaving product under Art. 7a of the Electricity Regulation, which is a temporary regulated instrument usable only during a declared price crisis. One of four flexible contract types identified by the Commission alongside dynamic, time-of-use and hybrid. See Demand Response › Contract types carrying the implicit signal. (Source - COM(2026)850 Retail Flexibility Report)

Co-design (DSO mechanism design principle) The principle that network tariffs, flexible connection agreements (FCAs), and local flexibility markets should be designed jointly rather than independently, because the three mechanisms interact. Since FCAs can pre-empt market resources, network tariff signals can crowd out market bidding incentives, and market clearing rules affect how FCA holders can participate, designing them in isolation risks redundancy, conflicting incentives, or — in the worst case — definite incompatibility (a “red condition”). The practical co-design implication for Swedish DSOs: sequence the mechanisms (market-based procurement first, FCAs as backstop) so that FCA activation displaces market activation rather than duplicating or contradicting it. See Flexible Connection Agreements, Flexibility Market › DSO mechanism co-design — the interaction challenge. (Source - DSO Service Acquisition Interaction Comillas (2024))

Congestion area (NODES platform term) The geographic unit of procurement in the NODES flexibility market platform. Each congestion area corresponds to an order book; the DSO defines which areas exist in its network. Areas can be linked vertically so that sell orders in a local area are visible to buyers at higher grid levels (regional DSO, TSO), and buy orders flow down to linked sub-areas — enabling cascade-model or common-market coordination without duplicating procurement infrastructure. Not to be confused with the general concept of congestion management; this is a NODES-specific platform architecture term. See NODES › Congestion area linking, Congestion Management. (Source - NODES FPM Presentation (2026))

Contingency (Swedish: oförutsedd händelse) An unpredictable future event — most often an unplanned component outage — used as the unit of analysis in both the deterministic N-1 criterion (which considers first-order contingencies: any single component failing) and in stochastic operational-risk assessment, where higher-order contingencies (two, three, or more components) are weighted by their joint probability within a defined lead time. See also CNEC, driftrisk. (Source - Energiforsk 2026-1165 Stokastisk Driftsäkerhet Transmissionsnät (2026))

Congestion management Actions taken by system operators when the grid cannot accommodate all requested power flows. Includes redispatching, countertrading, bidding zone price signals, local flexibility procurement, and curtailment. See Congestion Management. (Regulation Art. 13; Directive Art. 32)

Connecting system operator (NC DR term) The system operator to whose system a Controllable Unit is directly connected. Responsible for: CU module grid prequalification, setting temporary limits, and data exchange about CU characteristics. Distinct from the procuring system operator (who buys the service) and the impacted system operator (whose grid is affected by activation). (Source - NC DR Amended Text (ACER Recommendation 01-2025 Annex 1))

Controllable Unit (CU) (NC DR term) The atomic building block of flexibility market participation. A single demand facility, generation module, storage facility, or ensemble thereof behind one metering/connection point. Examples: a battery, heat pump, EV charger, industrial process. Every flexibility resource must be registered as a CU before market participation. Small CU: ≤50 kW — receives simplified qualification procedures and is exempt from CU-level near real-time data requirements. See Network Code on Demand Response. (Source - NC DR Amended Text (ACER Recommendation 01-2025 Annex 1))

Countertrading Cross-border variant of redispatching — a TSO buys energy in one direction and sells in another to relieve a constraint.

CPO — Charge Point Operator Operator of EV (electric vehicle) charging infrastructure. In the context of Villkorade Avtal and OpenADR, CPOs are the primary customer class driving standardization: CPOs with large charging depots want to connect ahead of grid reinforcement, accept conditional curtailment rights in return, and must integrate with the DSO’s OpenADR VTN to receive activation signals. A CPO operating in multiple grid territories was the strongest argument for a single industry protocol — otherwise each DSO would implement differently. The Energiföretagen Sverige working group that produced the 2023 recommendation included both DSO and CPO representatives. In some cases, an aggregator or payment service provider may act as agent for the CPO in the activation flow. See OpenADR, Villkorade Avtal. (Source - Energiföretagen Branschrekommendation Conditional Grid Connections (2023))

CU Module Operator (IA DR role) The party responsible for operating the CU-module of the FIS (Flexibility Information System). Manages CU registration data and data exchanges in the CU registration processes (Processes 1–8 in the IA DR Phase 1 scope). One of several new role types introduced by the IA DR that sit above the CU-level roles defined in the NC DR itself.

CU Operator (NC DR term) The party responsible for operating one or more Controllable Units. Can be the customer themselves or a delegated third party.

Curtailment Reducing generation or load output, typically as a last resort when other Congestion Management measures are insufficient.

Cutting the cable Colloquial term (from a 2026 CGE welfare analysis) for restricting electricity export capacity — via a formal export quota, denied interconnector approval, or reduced transfer capacity — to keep domestic prices below the international market price and protect electricity- and export-intensive (EEI) industries. See Electricity Export Restrictions.

D

Datahanteringsverktyg (Swedish: centralt datahanteringsverktyg) “Central data management tool” — the government’s 2025 replacement for the elmarknadshubb concept. Assigned to Ei (coordinating) and Svenska kraftnät on 2025-09-18; the joint proposal including legislative proposals and cost/timeline analysis was delivered in September 2026 (Ei R2026:08); the government has not yet decided. Four stated purposes: (1) improve flexibility and grid use via better data access; (2) streamline actor data exchange; (3) improve statistics and policy analysis; (4) simplify EU/national legislation implementation. Explicitly named as Sweden’s vehicle for implementing the NC DR’s FIS requirement. See Elmarknadshubb. (Source - Uppdrag Centralt Datahanteringsverktyg (2025))

Debiteringsgrundande effekt (Swedish) The specific peak power value (kW) determined from timmedeleffekter measurements and used as the basis for calculating a customer’s effektavgift charge. The calculation method varies by DSO — Ei PM2026:07 documented four approaches among the five supervised companies: single highest timmedeleffekt of the month (BTEA); average of the three highest timmedeleffekter occurring in different calendar days (Ellevio, GENAB, SHK); average of the five highest timmedeleffekter in different days (TVL). The choice of method materially affects both the price signal (predictability for customers) and revenue stability (for DSOs). A core design variable in effektavgift model development. (Source - Ei PM2026-07 Effektavgift Supervision)

Dedicated measurement device (DMD) A device linked to or embedded in an asset that provides demand response or flexibility services on the electricity market or to system operators. Introduced by Regulation 2024/1747 Art. 2(78). Enables TSOs, DSOs, and aggregators to use device-level metering for observability and settlement of flexibility services even where smart meters are not installed — removing a key barrier for flexibility participation at distribution level. Subject to customer consent; member states establish validation rules. Art. 7b of Regulation 2024/1747 creates a customer right to install DMDs.

DMD data can serve two quality tiers: settlement-grade (calibrated, certified, usable for billing and market settlement) and indicative (sufficient for operational decisions, baseline calculations, and DSO observability, but not for direct billing). Most flexibility applications require only indicative-grade — treating all applications as requiring settlement-grade is identified as a deployment barrier. See Submetering. (Regulation 2019/943 Art. 2(78), as amended by Regulation 2024/1747 Arts. 2(78) and 7b; Source - Electricity Market Design Reform Regulation (EU 2024-1747), Source - Submetering for Flexibility Services Comillas (2024))

Driftrisk (Swedish — “operational risk”) In stochastic/probabilistic grid-security assessment, the quantified risk of a given transmission network operating state, calculated as the sum over all considered contingencies of each contingency’s probability multiplied by its severity factor (allvarlighetsfaktor). The explicit quantification that the deterministic N-1 criterion never provides. See N-1 Criterion. (Source - Energiforsk 2026-1165 Stokastisk Driftsäkerhet Transmissionsnät (2026))

Demand response (DR) A change in electricity consumption patterns in response to price signals (implicit) or explicit requests/commands (explicit). See Demand Response. (Directive Art. 2(20))

DER — Distributed energy resources Small-scale generation, storage, and flexible loads connected at the distribution level. Examples: rooftop solar, batteries, EV chargers, heat pumps.

Derogation Regulatory exception allowing departure from default rules (e.g., non-market-based congestion management, DSO storage ownership) where justified and approved by the national regulatory authority. Subject to periodic review. (Directive Art. 32(1), Art. 36)

Digital station (Swedish: digital stamnätsstation) A substation control paradigm where most functions run in networked, interconnected software rather than discrete hardware — less physical equipment and copper cabling, earlier pre-installation testing, shorter build time, and remote fault detection without site presence. Functionally identical to a conventional Substation in grid role. Svenska kraftnät’s first, station Åker (Strängnäs), went live 28 July 2026 as Sweden’s first digital transmission substation; Ockelbo and Lindbacka are planned next. Framed by Svk as necessary to sustain its transmission-grid buildout pace at an affordable resource cost per station. (Source - Svk Digital Substation Åker (2026))

Direktordrar (DO) “Direct orders” — the spot product on SWITCH for procuring flexibility at short notice (up to 2 days before delivery). No availability fee; FSP is paid only for actual activation. Two variants: DA (day-ahead, clearing D-1 09:30–10:30) and ID (intraday, clearing H-3, activation H-2). Functions as the last market mechanism before villkorade avtal. See also: SWITCH › Products, Glossary › Säsongstillgänglighet (ST), Glossary › Tillgänglighetsordrar (TO). (Source - SWITCH User Documentation (2026))

DIS — Dynamiskt inköpssystem “Dynamic procurement system” — E.ON’s method for continuously recruiting flexibility service providers (FSPs) to SWITCH markets while complying with LUF (public procurement law for utilities). DIS allows ongoing open recruitment without triggering direct-procurement thresholds. An alternative to time-limited procurement rounds; new FSPs can be onboarded even during an active market season. SWITCH is adapted to the DIS workflow. (Source - SWITCH User Documentation (2026))

Dynamic electricity price contract EU legal definition (Directive (EU) 2019/944): an electricity supply contract between a supplier and a final customer that reflects the price variation in the spot markets, including day-ahead and intraday, at intervals at least equal to the market settlement frequency. Every customer with a smart meter has the right to one, from at least one supplier and from all suppliers with more than 200,000 customers in the country (Art. 11). Suppliers must disclose the benefits, costs and risks before the customer signs. Available to households in 16 member states but above 5% penetration in only five (Finland, Latvia, Netherlands, Sweden, Spain); switching and actively managing consumption is estimated to save up to 40%. The Swedish retail equivalent is timprisavtal. See Demand Response › Contract types carrying the implicit signal. (Source - COM(2026)850 Retail Flexibility Report)

Distribution transformer Transformer stepping voltage down from medium voltage (roughly 6–20 kV in Swedish local grids) to utilization voltage (230/400 V) for end customers. A key capacity bottleneck in the distribution grid as electrification increases. See Distribution Transformer.

DNDP — Distribution Network Development Plan (Swedish: nätutvecklingsplan) Mandatory DSO planning document covering the next 5–10 years (at least 10 years recommended). Required biannually under Directive 2019/944 Art. 32(3). The NC DR (Arts. 43–44) specifies mandatory content: planning framework, scenarios (5–10 year, coordinated with transmission plans), investment plans for assets and metering, and — where local services are relevant and cost-effective — a local services assessment with forecasted needs, cost-effectiveness methodology, and medium/long-term estimates with locational granularity. Minimum 6-week public consultation. NRA may request amendments.

The DNDP uses a three-pillar planning process: (1) scenario development, (2) grid capacity needs identification, and (3) project identification and selection. Solutions in pillar 3 may be grid reinforcement (new/upgraded lines, substations, transformers) or non-wire alternatives (flexibility procurement, villkorade avtal, storage).

ACER/CEER (2025) confirmed that DNDPs are “the primary source of DSOs’ data and analyses” for the FNA, and that DSOs should use the FNAM Tabell 15 format in the DNDP flexibility section. Submitted to the national regulatory authority (Ei in Sweden). In Sweden, Ei issues both a template and guidelines; DNDPs are published centrally on Ei’s website. Sweden is one of only 4 EU countries (with Denmark, Portugal, Slovenia) that quantify flexibility needs in DNDPs. See Distribution Network Development Plan. (Source - NC DR Amended Text (ACER Recommendation 01-2025 Annex 1), Source - ACER CEER DNDP Guidance (2025))

DNO — Distribution Network Operator Older term for the same entity now generally called DSO — the distinction is more than a rebrand: “network operator” implies owning, maintaining, and repairing the grid, while “system operator” implies actively following, controlling, and assessing the grid while it is in operation (real-time monitoring, active switching, proactive fault anticipation), not just reacting to faults after they occur. (Source - Från DNO till DSO LinkedIn Artikel (2026))

DSO — Distribution system operator Entity operating the medium- and low-voltage distribution grid. Must act as a neutral market facilitator. In Swedish: elnätsföretag. Examples: E.ON Energidistribution, Ellevio, Vattenfall Eldistribution. (Directive Art. 31–36)

Dubbelbeskattning (Swedish) “Double taxation” — a barrier to Vehicle-to-Grid deployment in Sweden. Electricity charged into an EV battery incurs energiskatt (energy tax) and moms (VAT). If that same electricity is subsequently discharged and sold via V2G, the receiving customer is taxed again on the same kWh. Skatteverket introduced a refund mechanism for energy tax on electricity fed back to the grid, but the refund applies only when discharging within the same concessionary network (koncessionsområde) where the electricity was originally charged. A consumer who charges in one area and discharges in another loses the refund right, constraining cross-area V2G and mobile use cases. (Source - KTH Thesis V2G Sweden 2024)

Dynamisk belastbarhet (Swedish) — dynamic loadability / dynamic rating Allowing a line’s or transformer’s loading limit to vary in real time with conditions (temperature, wind) instead of a fixed conservative rating, to free capacity. The headline technical capacity-release measure; for the overhead-line case see Dynamic Line Rating (DLR). Dutch DSO Liander freed 20–30% in bottlenecks this way, with a 120%-of-nominal ceiling where technically possible (trade-offs: higher losses, some shorter component life). (Source - Energiforsk 2026-1190 Kapacitet för Tillväxt (2026))

E

EAM — Energy Activation Market The cross-border mFRR activation market operated under ENTSO-E’s MARI platform. Svenska kraftnät launched the mFRR EAM on March 4, 2025, completing Sweden’s transition to pan-European mFRR activation following the 15-minute imbalance settlement period (EB GL Art. 53). Enables Nordic BSPs to submit mFRR energy bids that can be accepted by any TSO connected to the platform. See MARI, Balancing Markets. (Source - Svk Balancing Market Outlook 2030 (2024)) The same term is used for the coming aFRR EAM on the PICASSO platform, which Sweden plans to join in Q4 2027. (Source - Svk aFRR Energy Activation Market Implementation Guide (2026))

EB GL — Electricity Balancing Guideline Commission Regulation (EU) 2017/2195 establishing guidelines for electricity balancing. The primary EU regulation governing balancing markets. Key mandates: BSP/BRP role definitions (Arts. 16–17); TSO national terms obligation including cross-BRP aggregation rules (Art. 18); three European balancing platforms for FRR/RR exchange (Arts. 19–21); 15-minute imbalance settlement period (Art. 53); demand flexibility on equal terms with generation (Art. 3.1.f). Consolidated through 2022-06-19. See Source - EB GL (Regulation 2017-2195).

EEI industries — Electricity- and export-intensive industries Sweden’s iron/steel, non-ferrous metals, and pulp/paper sectors — identified as combining the highest electricity intensity (direct and indirect) with the highest export intensity in the Swedish economy. Together only ~4% of production and ~2.5% of value-added/wages, despite >10% of exports — a small footprint that is central to the finding that targeted subsidies protect them far more cheaply than economy-wide export restriction. See Electricity Export Restrictions. (Source - Cutting the Cable CGE Analysis (Böhringer Kriström 2026))

Ediel The Swedish electricity market’s standard for electronic information exchange between market actors, based on EDIFACT. All Swedish electricity market actors must pass Ediel tests and sign an Ediel-avtal with Svenska kraftnät before participating in the market; Svenska kraftnät operates Edielportalen as the test and registration system. Key message families: PRODAT (structural data — contracts, connections, customer info, meter data access requests Z01–Z18); UTILTS (meter value time series); DELFOR (plans and forecasts); APERAK (application-level acknowledgement); CONTRL (syntax-level acknowledgement). The Z-code series within PRODAT covers all process types; Z13–Z18 were added to support the Berättigad part meter data access mechanism (Z13 = request, Z14 = DSO confirm/deny, Z15 = termination notice from DSO, Z18 = berättigad part termination request). Contrast with the planned DHV/FIS — the future centralt datahanteringsverktyg that will complement or partially replace Ediel for flexibility-related data exchange. See Elmarknadshubb. (Source - Svensk Elmarknadshandbok 26A (2026))

Effektavgift / Effekttariff (Swedish) Capacity-based distribution tariff where part of a customer’s grid fee is determined by peak power consumption (kW or kWh during declared peak hours), not purely energy volume (kWh). Also called tidsindelad effektavgift when the applicable hours vary by time-of-day or season. Creates an implicit Demand Response incentive: customers who shift load away from peak hours reduce their capacity charge. As of 2024, only ~14% of Swedish DSOs use effektavgift and ~10% use time-differentiated variants (Ei Flexläget 2026). A known structural problem: when DSOs have incompatible effektavgift designs, standardized automated control signals from aggregators cannot reliably trigger the right behavior across multiple grid territories — this is the effekttariff integration gap identified by AFRY (2023). See Demand Response, Distribution System Operator. (Source - Ei Effektavgifter webb (2026), Source - AFRY Styr och Informationstjänster Konsumenter (2023))

Effektavgiftsgrundande mätvärde (Swedish) “Capacity-charge-basis meter value” — the one or more metered values a DSO uses to compute a customer’s effektavgift (e.g. the highest hourly mean power of the month, or the mean of the N highest hours/quarters). Defined in EIFS 2026:8 (2 kap.), which from 1 January 2027 requires DSOs that apply an effektavgift to display these values on mina sidor with date/time stamps and an explanation of how they feed the charge, and to show them (or a pointer) on the invoice — part of the effektavgift-transparency duty motivated by the surge in consumer confusion over how peak charges are calculated. Distinct from högsta mätvärde (the highest meter value in a series) — an effektavgiftsgrundande mätvärde is specifically the value(s) the charge is built on. See Demand Response, Source - EIFS 2026-8 Nätföretags Information till Elanvändare (2026).

Effekthandel Väst Local Flexibility Market in Gothenburg operated by Göteborg Energi Elnät and Mölndal Energi Elnät. Uses the NODES platform. Active from V2021/22 (now in its 4th+ season). One of three active Swedish flex markets as of 2025. See Effekthandel Väst. (Source - Sweco Kartläggning av lokala flexibilitetsmarknader (Ei, 2025))

Effektiviseringsincitament / effektiviseringskrav (Swedish) The cost efficiency incentive in Ei’s revenue cap regulation (intäktsramsreglering) for Swedish DSOs. Benchmarks each DSO’s costs against peers and translates the result into an adjustment to the next supervisory period’s revenue frame. For RP4 (2024–2027), only påverkbara (controllable operating) costs are benchmarked with a minimum 1% annual efficiency deduction. For RP5 (2028–2031), Ei is transitioning to a TOTEX framework covering both capex and opex — see Enstegsmetoden. Key confirmed RP5 design parameters: full cost coverage at the third quartile (Q3, relative threshold); no separate general efficiency requirement; 8-year realiseringstid. (Source - Ei Effektiviseringsincitament Webb (2026-05-12), Source - Ei Inriktning intäktsramar 2028-2031 (2025))

Effektivt nätutnyttjande (Swedish) — efficient grid utilisation Defined in Ei’s föreskrift EIFS 2023:6 (3 kap. §11) as “low network losses and even power in the grid” (låga nätförluster och en jämn effekt i nätet). The benchmark against which Swedish capacity-release measures are judged — and a subtle constraint: measures that raise total costs through extra losses or component wear (e.g. running lines hot under dynamic rating) can be argued to work against efficient utilisation in this Swedish sense, unlike the loss-accepting approach used abroad. See Grid Capacity Utilization. (Source - Energiforsk 2026-1190 Kapacitet för Tillväxt (2026))

Effektprognoser.se Digital portal providing municipal-level power demand forecasts for Skåne municipalities, produced by Region Skåne as part of the Skånes Effektkommission programme. Data underlying Source - Effektprognoser Skåne Region Skåne (2025): sector-by-sector power (MW) and electricity (MWh) demand for 2022–2040 for all 33 Skåne municipalities. Useful for DSO DNDP planning, municipal spatial planning, and investor establishment analysis. Uses the Energiforsk lathund methodology (Energiforsk 2024:1006). (Source - Effektprognoser Skåne Region Skåne (2025), Skånes Effektkommission)

Ei — Energimarknadsinspektionen Swedish Energy Markets Inspectorate. The national regulatory authority (NRA) overseeing DSO flexibility procurement, network tariffs, and market design.

Elastisk efterfrågan (Swedish) — elastic demand A feature of the Nordic mFRR budväljare, introduced 22 June 2026, that lets the bid selector leave part of a TSO’s balancing-energy need un-activated when the offered price is judged too high — a willingness-to-pay ceiling that dampens extreme imbalance prices. Capped at 70 MW per quarter-hour (with aFRR as backstop), it replaces the toleransband. Coordinated Nordically (Denmark and Norway live, Finland to follow) and designed to survive the MARI connection. See Balancing Markets, Nordic Balancing Model. (Source - Svk Elastisk Efterfrågan mFRR (2026))

Elberedskap (Swedish) Emergency preparedness for electricity supply — Sweden’s policy framework for maintaining grid function during crises and war. Svenska kraftnät acts as elberedskapsmyndighet (grid preparedness authority). Relevant to Island Operation because ö-drift capability is explicitly funded through elberedskapsanslag (preparedness grants), providing an alternative revenue channel for microgrid/islanding projects alongside DSO cost recovery. Both the Arholma (Vattenfall Eldistribution) and Simris (E.ON Energidistribution) projects reference elberedskap as a motivation. The Skåne feasibility study (2023) found no suitable island object but assessed elberedskapsanslag + ancillary service revenue stacking as the viable funding model where a project does exist. See Island Operation. (Source - Svk Om Ö-drift (2025))

Ellagen Swedish Electricity Act (1997:857) — the primary legislation governing the Swedish electricity market. Subject to amendments for CEP transposition. Key provisions for flexibility: DSOs must procure non-frequency ancillary services market-based (3 kap. 4 §), DSOs cannot conduct non-network business (3 kap. 12 §), pilot tariffs allowed (4 kap. 31 §), network development plans required (3 kap. 16–17 §§). Repealed and replaced from 1 January 2027 by the new Elmarknadslagen + lag om elektriska ledningar (Prop. 2025/26:240).

Elmarknadshubb (Swedish) The original name for Sweden’s planned central electricity market data hub. Svenska kraftnät was assigned to build it in 2015 (M2015/2635/Ee); the project paused in 2020 waiting for legislation. In September 2025, the government cancelled the old mandate entirely and issued a new assignment — a centralt datahanteringsverktyg — jointly to Ei (coordinating) and Svk, whose joint proposal was delivered in September 2026 (Ei R2026:08). The new tool starts from the current market model, not a supplier-centric redesign. See Centralt Datahanteringsverktyg for full history and the current proposal. (Source - Projektstatus Elmarknadshubben (2021), Source - Uppdrag Centralt Datahanteringsverktyg (2025))

Elmarknadslag (Swedish: Electricity Market Act) — SFS 2026:1281 The new act replacing the 1997 ellagen’s market-function rules, adopted by the Riksdag 15 June 2026 (Prop. 2025/26:240), promulgated 18 June 2026 as SFS 2026:1281, in force 1 January 2027. Regulates the electricity market’s function (21 chapters): transport, delivery, system responsibility, the balance market (codifying BRP and BSP as legal roles), aggregation services (ch. 13), energy sharing (ch. 14), and consumer protection. Renames nätföretag → systemansvarig and transmission → överföring. A companion lag om elektriska ledningar (SFS 2026:1283) takes the grid-concession rules. Together they repeal the ellagen. See Elmarknadslagen. (Source - Elmarknadslag (2026-1281))

Lag om elektriska ledningar (Swedish) — SFS 2026:1283 The companion act to the Elmarknadslag, holding the nätkoncession (grid-concession) and electric-lines rules formerly in the ellagen (13 chapters). Promulgated 18 June 2026, in force 1 January 2027. Mostly minor changes from the ellagen — notably, the rule on choosing between an overhead line and an underground/sea cable now applies also at amendment/omprövning of a line concession. See Elmarknadslagen, Source - Lag om Elektriska Ledningar (2026-1283).

Elnätsföretag (Swedish) Grid company / distribution system operator (DSO). See DSO.

EMDO — Electricity Market Data Ontology Svk‘s published RDF/Turtle ontology for electricity-market data — a machine-readable vocabulary defining reserve products and directions, bidding zones and interconnectors, production types, auction rounds, forecast horizons, units of measure, country codes, and trade-action directions. Paired with the BASE ontology (general concepts); both published openly at data.svk.se and used to describe Svk’s open datasets. A semantic data model — it defines what market data means, distinct from the device-communication protocols in Flexibility Communication Protocols; same family as the IEC CIM but narrower (market data) and Svk-authored. Relevant to the structured, machine-readable data the NC DR FIS and the DHV require. See Source - Svk EMDO BASE Ontologier (2026).

Energidelning (Swedish) — energy sharing The activity of sharing electricity between members (as opposed to energigemenskap, the organisational form). Ei’s proposed definition: an electricity user’s self-consumption of renewable energy produced or stored in an owned, rented or leased facility, or transferred from another producing user. Swedish law enables it from 1 January 2027 (Prop. 2025/26:240) within one elområde, via supplier-side deduction of the shared volume — criticised as the minimum EU-directive implementation. Three execution routes with different fee/tax treatment: virtuell delning (via the existing grid, full network fees), eget kompletterande nät (IKN, behind the meter, some fees exempt), and helt eget nät (exceptional cases only). See Energy sharing (the EU-law term), Energy Communities. (Source - Power Circle Energigemenskaper Faktablad (2026))

Energigemenskap (Swedish) — energy community An association of members that jointly consume, produce, store and/or sell energy. No formal Swedish legal definition as of 2026 (the Riksdag rejected adding one); EU defines two types — medborgarenergigemenskap (CEC) and gemenskap för förnybar energi (REC). The organisational form that can use energidelning as a tool. ~200 exist in Sweden (mostly pilots) vs ~9,000 in the EU. See Energy Communities. (Source - Power Circle Energigemenskaper Faktablad (2026))

Energitjänsteföretag (Swedish) The Edielportalen label for a Berättigad part — the same actor type but as registered in Svenska kraftnät‘s test and registration system. Used interchangeably with berättigad part in practice. The distinction is purely administrative: berättigad part is the legal/handbook term; energitjänsteföretag is the technical identifier on Edielportalen.

Energiupplösning (Swedish) — energy resolution The time granularity (e.g. quarter-hour, hourly, monthly) at which a meter value is registered or reported. A DSO can register a value at one resolution internally while reporting it downstream at a coarser one — Ei found in 2023 “strong indications” that many Swedish DSOs do exactly this, e.g. metering a customer quarter-hourly/hourly but reporting only monthly values to the supplier, in breach of mätföreskrifterna 7 kap. 1 § (report at the resolution registered). The distinction matters because correctly measured data can still fail to reach a forecasting or settlement system at the resolution it needs — a separate failure mode from a missing value outright. See Load Forecasting › Data challenges in flexibility contexts. (Source - Ei Tillsyn Mätning och Rapportering (PM2024-02))

Energy storage Technologies that absorb electricity and release it later. Includes batteries, pumped hydro, thermal storage, hydrogen, flywheels. See Energy Storage. (Directive Art. 2(59), Art. 36)

Enstegsmetoden (Swedish) “The one-step method” — Ei’s chosen TOTEX application method for the RP5 (2028–2031) efficiency incentive, confirmed December 2025. Process: (1) before the supervisory period, benchmarking compares companies’ historical TOTEX efficiency and produces an individual efficiency percentage for each DSO; (2) after the period, this percentage is applied to the company’s actual total cost outturn during the period; (3) the result adjusts the next period’s revenue frame. The company knows in advance how its revenue frame will be affected as a share of costs, but the absolute amount depends on actual costs incurred. Distinguished from Tvåstegsmetoden (two-step, where a pre-period requirement is set and then measured against actual post-period costs) and Norsksvenska metoden (pre-period score applied to actual post-period TOTEX, zero-sum within the industry). (Source - Ei Effektiviseringsincitament Webb (2026-05-12))

ENTSO-E — European Network of Transmission System Operators for Electricity TSO coordination body. Joint author (with EU DSO Entity) of the NC DR proposal. Develops network codes and system adequacy assessments.

EPAD — Electricity Price Area Differential Financial contracts that let market participants hedge the price difference between bidding zones. Svenska kraftnät has auctioned EPADs for SE2, SE3 and SE4 since 7 February 2023 (monthly, quarterly and yearly contracts covering about 15% of the SE2–SE3 and SE3–SE4 transmission capacity), brokered by Svensk Kraftmäkling. See EPAD Auctions. (Source - Svk EPAD Auctions Q1 2026 and Trading Rules (2026))

ERAA — European Resource Adequacy Assessment ENTSO-E’s biennial pan-European study assessing whether the electricity system will have sufficient generation to meet demand. Uses probabilistic scenarios (National Trends / Central Reference as the base case). Svk uses ERAA scenarios as input to the system-flexibility component of Sweden’s Flexibility Need Assessment. ERAA 2025 is the source for Svk’s 2030/2035 capacity and DSR projections used in FNA 2026. (Source - FNA Webinar 7 (2026-03-16))

E-Redes Portugal’s sole distribution system operator (DSO), formerly EDP Distribuição (renamed 2021). Operates ~100% of Portugal’s distribution network. Produces the PDIRD-E and operates the FIRMe local flexibility market via the Piclo platform. Equivalent role to the six large Swedish DSOs combined (Vattenfall, E.ON, Ellevio, etc.), but as a single national operator. See Flexibility Market › FIRMe — Portugal’s operational flexibility market, Source - ERSE Parecer PDIRD-E 2024.

ERSE — Entidade Reguladora dos Serviços Energéticos Portugal’s energy markets NRA (National Regulatory Authority). Issues binding opinions on E-Redes’ PDIRD-E, runs mandatory public consultations, and can require amendments to the plan. ERSE’s role is stronger than Sweden’s Ei: Ei is ex-post (tillsyn) only and cannot compel DSO plan changes; ERSE issues a binding opinion that must be addressed before the plan receives government approval. (Source - ERSE Parecer PDIRD-E 2024)

eSett (eSett Oy) — Nordic imbalance settlement company The TSO-owned (Svenska kraftnät, Fingrid, Statnett, Energinet) entity that performs imbalance settlement, invoicing, and collateral management for every BRP and BSP in SE/FI/NO/DK — the region’s Imbalance Settlement Responsible (ISR) under the EB GL, operating the Nordic Balance Settlement (NBS) model on a 15-minute ISP (Sweden since March 2025). Defines the VoAA (Value of Avoided Activation) + Incentivizing Component compensation architecture for cross-BRP independent aggregation. Sweden is the only Nordic country with no national datahub, feeding eSett bilaterally via Ediel; the planned DHV will become Sweden’s MDA (Metered Data Aggregator) and absorb eSett’s Sweden-specific reconciliation/profiling. See eSett, eSett’s Swedish Role Through NC DR Implementation. (Source - Nordic Imbalance Settlement Handbook v5.2 (2025))

EU DSO Entity European association of distribution system operators. Joint author (with ENTSO-E) of the NC DR proposal. Coordinates DSO positions on network codes.

Explicit flexibility / explicit demand response Flexibility activated through direct dispatch signals — the resource owner pre-commits and an aggregator or system operator activates. Corresponds to market-based flexibility. Contrast with implicit flexibility.

F

Fastlagda tillgångar (Swedish) — Pre-arranged/reserved assets The standard MSB/Socialstyrelsen (now MCF) civil-defence supply-preparedness (försörjningsberedskap) model’s core concept: assets formally secured for wartime use ahead of time — contracted stockpiles, statutory reserves, state-owned stock, or reserved production capacity — organised into five categories (A: end-user reserves, B: pre-distribution reserves, C: state stockpiles, D: reserved production capacity, E: international reserved arrangements). The ResiliENt Syd pilot found this model fits electricity poorly, since electricity cannot be stockpiled the way physical goods can. See Beredskapsflexibilitet. (Source - Energimyndigheten ER 2026-21 ResiliENt Syd (2026))

FCI — Flexibility Commitment Index (UK) An incentive in the UK’s RIIO revenue regulation that rewards a DSO for how well it uses flexibility to defer or replace traditional reinforcement projects — i.e. it pays network companies for choosing flexibility over building. Paired with Use-or-Explain (for every major reinforcement the DSO must justify why flexibility was not the most cost-effective option) and with “slow money” (long OPEX depreciation that puts flexibility spend on par with capex in the asset base). Together the clearest existing example of revenue regulation that actively rewards flexibility — a reference point for Sweden’s RP5 TOTEX reform. See RP5 Revenue Cap Methodology (2028–2031) › International reference points for RP5 (Energiforsk 2026:1175), Grid Capacity Utilization › The revenue-regulation dimension. (Source - Energiforsk 2026-1175 Kapacitet för Tillväxt Intäktsreglering (2026))

FCR-D — Frequency Containment Reserve – Disturbance Balancing product activated automatically within seconds to arrest frequency after a large disturbance (e.g., generator trip). Upward only. See Balancing Markets.

FCR-N — Frequency Containment Reserve – Normal Balancing product activated automatically to maintain continuous frequency regulation around 50 Hz. Symmetric (up and down). See Balancing Markets.

FDIR / FLISR — Fault Detection, Isolation, and Restoration / Fault Location, Isolation, and Service Restoration (also: self-healing grid, Swedish: självläkande nät) Two names for the same distribution-automation pattern — FDIR more common in European literature, FLISR in North American/vendor literature — combining grid-mounted fault indicators, remotely controlled switching devices, and decision-support software to locate a fault and propose a network reconfiguration that restores power to as many customers as possible before a field crew reaches the physical fault. The logic only works as well as the underlying physical network allows: a system can compute a perfect alternative switching plan in seconds, but the calculation is moot without a physical alternative feed path — meaning redundancy investment (extra feed points, remote-controlled breakers, dual transformers at high-consequence sites) is a precondition for FDIR/FLISR to pay off, not an optional extra. (Source - Från DNO till DSO LinkedIn Artikel (2026)) Vattenfall Eldistribution runs FDIR at MV-network scale (control-room operator confirms each proposed action; full autonomy is a stated future goal, not current practice) — distinct from the purpose-built Adaptive Power Restoration System (APRS) at its Arholma microgrid, which restores supply within a single islanding microgrid rather than across a general MV network. (Source - Vattenfall Eldistribution Självläkande Nät (2026))

FFR — Fast Frequency Reserve Ultra-fast frequency containment reserve responding within 0.7–1.3 seconds — faster than FCR — designed for grids with high inverter-based generation and low rotational inertia. Provided primarily by batteries and fast-responding hydro. In Sweden, FFR costs are currently recovered through the grid tariff (subscribers pay a fixed fee). Svenska kraftnät plans to transition FFR to a D-1 market in 2027, enabling competitive price discovery. See Balancing Markets. (Source - Svk Balancing Market Outlook 2030 (2024))

FIRMe — Flexibilidade Integrada em Regime de Mercado (Portuguese) “Integrated Flexibility in a Market Regime” — E-Redes’ local distribution flexibility procurement programme in Portugal. Operates on the Piclo platform. Three products: Dynamic (planned maintenance windows), Secure (congestion management estimates), Restore (post-fault network restoration). One of only 7 fully operational live local flexibility markets in Europe as of late 2025. Second auction (Nov 2025): 23 providers, 163 qualified assets, 82.9 MW, ~7× bid growth vs first auction. See Flexibility Market › FIRMe — Portugal’s operational flexibility market, Source - E-Redes FIRMe Programme.

FIS — Flexibility Information System (NC DR term) Mandatory national information system for all flexibility market participation, comprising a CU module (resource registration) and an SP module (provider qualification). Requires a single common access point with both GUI and API (ETSI-CEN-CENELEC standards). Data portability is required — all data must be exportable in structured, machine-readable format to prevent vendor lock-in. Register-once principle: SPs and system users enter data once; all SOs see it. Must reach full interoperability within 4 years of NC DR entry into force. Existing platforms (SWITCH, NODES) may continue as transitional IT solutions until the national FIS is implemented; must be updated or replaced within 2 years of FIS T&C approval. Also called flexibility register in earlier NC DR drafts. See Network Code on Demand Response. (Source - NC DR Amended Text (ACER Recommendation 01-2025 Annex 1))

Flaskhalsinkomster (Swedish) — Congestion revenues Revenues collected by transmission system operators when electricity prices differ between bidding zones — a direct result of transmission congestion between areas. Under EU rules (CACM Regulation and EMD Reform), these revenues must be used for specific purposes: reducing grid tariffs, maintaining or increasing cross-zonal capacity, or funding investment in interconnectors and grid reinforcement. The EU nätpaketet (network package, Commission proposal December 2025) proposes to restrict how member states can apply these revenues beyond these categories. Sweden has objected strongly, arguing that countries with internal price zones (SE1–SE4) should be able to direct the revenues to fossil-free dispatchable electricity production and grid support. See Congestion Management, Svenska kraftnät. (Source - Svk Utlandskablar Uppdrag Reviderad Investeringsplan (2026))

Flexible connection agreement (FCA) / villkorat avtal EU legal definition (Directive 2024/1711, Art. 2(24c)): “A set of agreed conditions for connecting electrical capacity to the grid that includes conditions to limit and control the electricity injection to and withdrawal from the transmission network or distribution network.” Directive 2024/1711 Art. 6a requires national regulatory authorities to develop mandatory frameworks for TSOs and DSOs to offer flexible connection agreements in areas with limited/no network capacity; transposition deadline 17 July 2026. The NC DR (Art. 31) adds three binding operational requirements: (1) treated as firm connections in needs assessments; (2) activation must coordinate with market-based procurement; (3) system users holding flexible CAs retain full rights to participate in local services and balancing markets. In Sweden the mechanism is known as villkorade avtal: the customer’s connection is split into guaranteed capacity and controllable capacity that the DSO can curtail during congestion — rules-based, explicit flexibility (Source - Ei Villkorade avtal (2023), Source - E.ON Guide villkorade avtal (2025)). Don’t confuse with “flexibla avtal” (flexible agreements, plural, no direct English-acronym equivalent) — a second, distinct instrument E.ON is developing as a permanent arrangement (vs. villkorat avtal’s temporary, last-resort role), aimed at large batteries and still under design dialogue with Ei, not yet an operational product. See E.ON Energidistribution › Second DNDP cycle — 2027–2036 (preliminary).

FCA design spans 10 dimensions across four meta-categories: temporal (advance notice, duration), locational/product (DER types, trigger conditions), network connection criteria (guaranteed capacity, access priority — first-come-first-served vs. LIFO vs. pro-rata), and activation/commercial (compensation, activation method). Key incompatibility risks with local markets: ex-post curtailment notification blocks day-ahead market participation; emergency activation with no advance notice makes combined use infeasible; LIFO priority undermines bid reliability. See Flexible Connection Agreements, Villkorade Avtal. (Source - Electricity Market Design Reform Directive (EU 2024-1711), Source - NC DR Amended Text (ACER Recommendation 01-2025 Annex 1), Source - DSO Service Acquisition Interaction Comillas (2024))

Flexible customer (NC DR term) A customer contributing to service provision via a service provider, whether through demand response, storage, or generation.

Flexibility EU legal definition (Regulation 2024/1747, Art. 2(79)): “The ability of an electricity system to adjust to the variability of generation and consumption patterns and to grid availability, across relevant market timeframes.” — The first codified EU legal definition of flexibility, introduced by the Electricity Market Design Reform 2024 in force from 16 July 2024. Working definition for this wiki: the ability to adjust electricity generation, consumption, or storage in response to grid needs — whether for balancing, congestion management, or power quality. The central concept of this wiki. See Flexibility. (Source - Electricity Market Design Reform Regulation (EU 2024-1747))

Flexibility market A market where system operators (typically DSOs) procure flexibility from distributed resources to manage local grid constraints. The CEP requires market-based procurement as the default (Directive Art. 32). See Flexibility Market.

Flow-based capacity calculation Method for determining available cross-zonal transmission capacity based on actual physical power flows (Kirchhoff’s laws), rather than simplified bilateral exchanges (NTC). Adopted in the Nordics October 2024. See Flow-Based Capacity Calculation. (Regulation Art. 14–16)

FNA — Flexibility Needs Assessment (Swedish: Flexibilitetsbehovsbedömning / Flexibilitetsbehovsanalys) Mandatory biennial national assessment of electricity system flexibility needs. Primary EU legal basis: Art. 19e of Regulation (EU) 2019/943 as amended by Regulation 2024/1747 (Electricity Market Design Reform 2024). Methodology established by ACER Decision 05-2025 (FNAM — FNA Methodology, published 25 July 2025). Two dimensions: system flexibility (balancing) and network flexibility (congestion/voltage). Reporting chain: lokalnät → regionnät → Svenska kraftnät → ACER + Commission. FNA is a needs description only — it does not determine who procures flexibility or how costs are allocated. Sweden’s first FNA is due July 2026. See Flexibility Need Assessment. (Source - Electricity Market Design Reform Regulation (EU 2024-1747))

FNAM — FNA Methodology The FNA Methodology established by ACER Decision 05-2025 (Annex I). Defines data types, formats, analytical methods, target years, geographic granularity, and coordination requirements for the Flexibility Need Assessment process. Applicable as national law in all EU Member States from 25 July 2025.

Förhandsbesked (Swedish) “Advance notice / preliminary decision” — Svenska kraftnät‘s preliminary statement to a connection applicant on whether and on what terms capacity can be made available at a transmission connection point, issued before a binding connection agreement. A key throughput metric for the connection process: Svk reports issuing förhandsbesked for >5,000 MW of inmatning and uttag in 2025/early 2026 and cutting the lead time to förhandsbesked by ~30%. (Source - Svk Mogna Initiativ Anslutning (2026))

Förmögenhetsbevarande princip (Swedish) “Wealth-preserving principle” for capital asset valuation: assets are valued at original acquisition cost (historiska anskaffningsvärden), adjusted for general inflation (KPI). Replaces the kapacitetsbevarande principen in Ei’s revenue regulation from RP5 (2028–2031) onward. Achieves net present value neutrality — DSO return matches the allowed WACC by construction. See intäktsramsreglering, Source - Ei Inriktning intäktsramar 2028-2031 (2025).

Försörjningsanalys (Swedish) — Supply/security-of-supply analysis A civil-defence planning methodology: behovsanalys (need analysis — identifying totalförsvarsviktig verksamhet from normal use, then estimating how that need changes under höjd beredskap) + tillgångsanalys (supply analysis) → gapanalys (gap analysis) → a feasibility×effect prioritisation of candidate measures. First tested for the energy sector by the ResiliENt Syd pilot (södra civilområdet, 2026), which found the methodology’s generic fastlagda tillgångar model fits electricity poorly. A national rollout of the methodology, using ResiliENt Syd as its template, was confirmed to begin in 2026. See Beredskapsflexibilitet › Försörjningsanalys — testing the preparedness-planning methodology (ResiliENt Syd). (Source - Energimyndigheten ER 2026-21 ResiliENt Syd (2026), Source - Energimyndigheten ER 2026-08 Energiomställningen (2026))

FSP — Flexibility Service Provider (also: flexibilitetsleverantör in Swedish) An entity offering flexibility to a system operator (DSO or TSO) through a flexibility market. In CoordiNet and Swedish market practice, FSPs include district heating companies, industrial loads, aggregators (of heat pumps, EV chargers, batteries), individual large consumers, and reserve power generators. Equivalent to the NC DR’s Service Provider (SP) role. (Source - CoordiNet D4.7.2 Swedish Demonstration (2022))

In Svk’s kompensationsmodell proposal (submitted September 2, 2024), FSP was proposed as a new statutory role — deliberately broader than “aggregator” to encompass all flexible resources (consumption, production, storage). Svk recommended renaming the existing “leverantör av aggregeringstjänster” to FSP/flexibilitetsleverantör. The FSP concept requires a central information system (estimated 4–6 years). See Aggregation › Svk’s compensation model proposal (2024). (Source - Elmarknadsrådet Meetings 3 and 4 2024 (Sep-Nov))

G

Garanterad överföringskapacitet (Swedish) Guaranteed transfer capacity — the power level always available to a customer under a villkorat avtal, regardless of grid conditions.

Grid prequalification (NC DR term) Process where connecting and impacted system operators verify that activating an SPU or SPG won’t compromise grid safety in their systems. Runs before or parallel to product prequalification; must not delay product prequalification. Results in one of three statuses (Art. 49): (1) “grid prequalification approved” — activation respects operational security limits; (2) “grid prequalification conditionally approved” — only under specified time and/or quantity conditions; (3) “grid prequalification not approved” — requires full justification including explanation of why temporary limits cannot address the issue. If a system operator does not communicate results before prequalification completes, grid prequalification is automatically approved. Annual reporting to NRA on non-approved and conditional cases. (Source - NC DR Amended Text (ACER Recommendation 01-2025 Annex 1)) In Sweden the closest existing mechanism is förkvalificering till elnätet under the draft SO GL Art. 182 agreement (remiss 30 September–26 October 2026): for FCR, aFRR and mFRR units or groups of at least 0.5 MW per grid area, the DSO decides within 4 working weeks, and a missed deadline counts as approval. (Source - Svk Energiföretagen SO GL Art 182 Avtal (2026))

H

Hybrid contract (retail electricity) A flexible retail supply contract blending a fixed pricing element with a flexible one, so the customer keeps some bill predictability while still capturing flexibility value. Variants identified by ACER-CEER include price caps limiting exposure to spikes, free or discounted hours encouraging load shifting, and EV-specific products combining flat off-peak rates with smart-charging incentives (including bidirectional discharge incentives). The Commission promotes hybrids as the route to consumers for whom full spot exposure under a dynamic electricity price contract is unsuitable, and asks member states to enable sandboxes and pilots for them. See Demand Response › Contract types carrying the implicit signal. (Source - COM(2026)850 Retail Flexibility Report)

HHI — Herfindahl-Hirschman Index A measure of market concentration calculated by summing the squared market shares of all participants. Used to assess competition levels; higher HHI indicates a more dominant firm (or few firms). Sweco (2025) recommends applying HHI to local flex markets to measure FSP concentration risk — given that a few large energy companies dominate activated volumes. (Source - Sweco Kartläggning av lokala flexibilitetsmarknader (Ei, 2025))

Hosting capacity The amount of generation (injection) or load (offtake/withdrawal) a grid connection point can accommodate before a network constraint is reached — a thermal/current limit or a voltage limit. No standardised EU-level definition exists yet; CEER’s 2026 smart-grid indicators paper notes it can be assessed both as an “actual” (recent, current) value and a forward-looking value (e.g. a 3-year-ahead expected capacity at HV/MV busbars), and that it varies with operating conditions over time. Proposed as one of two output indicators for renewable-generation integration (injection) and one for electrification (offtake) in CEER’s framework. See Digitalization and Smart Grid, Grid Capacity Utilization. (Source - CEER Electricity Smart Grid Performance Indicators (2026))

HVO — Hydrogenated Vegetable Oil Renewable drop-in fuel produced by hydrogenating vegetable or animal fats. Used as a substitute for diesel in combustion engines and industrial burners (elpannor). In the context of local flexibility markets, HVO enables fuel switching flex: an industrial elpanna can switch from consuming electricity to burning HVO for heat production, instantly reducing grid demand. Provides effectively unlimited flexibility endurance as long as the HVO supply can be replenished. At Kinnekulle Energi’s Götene market, Dafgårds operates a 5 MW elpanna on HVO fuel switching — the primary anchor FSP resource. (Source - Flexsäsongen i Götene 2024-2025 Sweco)

HVDC — High-voltage direct current Transmission technology used for long distances, submarine cables, and interconnecting asynchronous grids. Key Nordic interconnectors include Baltic Cable, Fenno-Skan 1–2, Konti-Skan 1–2, NordBalt, SwePol. Planned expansions (Konti-Skan Connect, Aurora Line 2, Fenno-Skan 3) were paused by the Swedish government in May 2026 as leverage in EU nätpaketet negotiations. See Electric Power Transmission, Svenska kraftnät.

I

IA DR — Implementing Act on Demand Response Companion EU implementing regulation to the Network Code on Demand Response, developed jointly by ENTSO-E and EU DSO Entity under Arts. 23–24 of Directive 2019/944. Specifies the data exchange processes, information model, and role definitions for how CU and SP registration, baseline calculation, and flexibility quantification are handled in the FIS. The IA DR is structured in two phases: Phase 1 (15 processes; submitted to EC Q2 2025) and Phase 2 (18 processes; submitted Q4 2025); entry into force estimated 2027. (Corrected 2026-09-23 — this entry previously said “3 additional processes” for Phase 2, contradicted by NC DR’s own Phase 2 breakdown and by the source page below, both of which list 18: SPG/U registration/qualification/switching/revocation, CU grid prequalification/switching/termination, product verification, flexibility product activation, flexible connection agreement management, temporary limits, bidding.) Introduces new role types not present in the NC DR text: CU Module Operator, SP Module Operator, Baseline Calculator, Baseline Provider, Quantification Aggregator. Based on a 5-layer EU reference model (business, function, information, communication, component). See Network Code on Demand Response. (Source - Svk IA DR Webinar Part 1 (2025))

IA compensation model The commercial arrangement governing how an independent aggregator (IA) compensates the customer’s incumbent supplier or BRP for imbalances caused by DR activations. Three models identified in EU practice: pass-through — the IA shares activation revenues with the supplier per a pre-agreed formula (dominant where BRPs have market leverage; aligns incentives but requires negotiation); flat fee — supplier receives a fixed payment per activation regardless of market outcome (simpler; IA retains upside/downside risk); hybrid — combines pass-through and flat-fee elements (emerging as balancing compromise). Choice of model shapes FSP incentives and the practical accessibility of independent aggregation. Governed by Art. 4 of Regulation 2019/943 (as amended) and national T&Cs developed under the Network Code on Demand Response. See Aggregation › IA compensation models and balance responsibility. (Source - Aggregators DR Relationships Comillas (2025))

Impact factor (PTDF — Power Transfer Distribution Factor; Swedish: påverkansfaktor) The fraction of a resource’s power change that affects flow at a specific constrained substation. Used in SWITCH and CoordiNet to create geographically weighted merit-order lists: a bid price is divided by the impact factor to calculate cost per MW of congestion relief at the target substation. Enables the DSO to procure flexibility from resources with the highest electrical impact on the specific bottleneck, not just the lowest bid price. Defined as time series (can be updated hourly; CoordiNet used static values for peak consumption patterns). (Source - CoordiNet D4.7.2 Swedish Demonstration (2022))

ICCP — Inter-Control Centre Protocol The standard real-time, SCADA-to-SCADA data-exchange protocol used between grid control centres (also standardized as IEC 60870-6/TASE.2). Distinct from IEC 60870-5-104, which is used for DSO-to-customer-equipment telecontrol: ICCP is specifically for control-centre-to-control-centre links, most commonly TSO↔DSO or TSO↔TSO. Used in the EU TDX-ASSIST project’s Portuguese TSO-DSO demonstrator to link REN’s and EDPD’s SCADA systems for real-time exchange of substation data, with non-real-time data (forecasts, maintenance plans) carried separately over SFTP/web-services. (Source - TDX-ASSIST Portuguese Demonstrator (CIRED 2019))

IEC 60870-5-104 Communication protocol for telecontrol, used for real-time data exchange between DSO systems and customer equipment in Villkorade Avtal implementation.

IEC 61850 International standard for communication in electrical substations and grid automation.

IKN — Icke-koncessionspliktigt nät (Swedish) A “non-concession-required net” — an internal electricity network exempt from the nätkoncession (grid licence) normally required to build/operate a line, governed by the IKN-förordning. Since 2022 it has been permitted to share electricity on such internal nets between residential buildings (previously only within a building, or dwelling→non-dwelling), which is what makes the eget kompletterande nät route for energy communities possible: own cables between included properties while each keeps its ordinary grid connection, with the shared electricity exempt from certain network fees because it does not pass the meter or the concession grid. Contrast with virtuell delning (full fees). See Energy Communities › IKN and the complementary-net route, Nätkoncession. (Source - Power Circle Energigemenskaper Faktablad (2026))

Impacted system operator (NC DR term) A system operator whose grid may be affected by the delivery of a flexibility service, but who is not the party procuring it. For example, a regional DSO (regionnät) whose cable becomes loaded when a local DSO (lokalnät) activates flexibility in its own area. Impacted SOs have the right to perform grid prequalification on SPUs/SPGs connected to other SOs’ systems that could affect their grid. Distinct from connecting system operator (where the CU is connected) and procuring system operator (who buys the service). (Source - NC DR Amended Text (ACER Recommendation 01-2025 Annex 1))

Implicit flexibility / implicit demand response Flexibility achieved through price signals — the consumer voluntarily adjusts behavior in response to tariffs or real-time prices. Corresponds to rules-based flexibility. Contrast with explicit flexibility.

Independent aggregator See aggregation.

Inmatningsabonnemang (Swedish) “Grid injection subscription” — a contract with the DSO that permits electricity to be exported (injected) into the grid from the customer’s connection point. Required for any Vehicle-to-Grid deployment: without an inmatningsabonnemang, an EV can only draw power from the grid (G2V), not discharge into it (V2G). Also required for solar PV microproducers. The need to establish an inmatningsabonnemang for each V2G installation is one source of administrative friction, particularly for mobile resources. (Source - Power Circle V2X Synthesis 2024)

ISO 15118-20 International standard for communication between an electric vehicle and the charging equipment (EVSE). Version 20 (published 2022) extends the standard to cover bidirectional charging (ISO 15118-20 = the enabling standard for V2G at the charging interface). Defines Plug & Charge authentication and the protocol layer that conveys vehicle state-of-charge and charging/discharging commands between car and wallbox. The DC variant of ISO 15118-20 is more mature than the AC variant — the AC standard lacks a standardized layer for state-of-charge data, which limits smart-charging optimization over AC connections. See Vehicle-to-Grid. (Source - Power Circle V2X Synthesis 2024)

Intäktsramsreglering (Swedish) Revenue cap regulation — the regulatory framework that sets the maximum revenue each DSO can collect from customers over a four-year period. Determined by Ei. Creates a CAPEX bias because capital investments earn regulated return while flexibility is OPEX. See CAPEX bias. (Source - Ei Flexibility in Distribution Grids (2023))

Intersection (Swedish: snitt) A transmission bottleneck boundary between Bidding Areas. Sweden has three: Intersection 1 (SE1↔SE2), Intersection 2 (SE2↔SE3), Intersection 4 (SE3↔SE4). Note: Intersection 3 is an internal east-west boundary within SE3.

Investeringsskuld (Swedish) — investment gap/debt The shortfall of initiated electricity-system projects (generation and grid) relative to what the 2045 electrification scenarios — e.g. the 300 TWh planning target — require, given that permitting and grid-connection lead times mean projects must be started long before the capacity is needed. Identified in Energiforsk’s NEPP lead-time study: the gap exists already today and even large lead-time improvements only partly close it. An execution/timing risk distinct from (and compounding) the question of whether demand will materialise. See Long-Term Market Analysis, Capacity Adequacy and Flexibility as the Missing Reserve. (Source - Energiforsk 2026-1185 Ledtider för Energiomställningen (2026))

K

Kapacitetsåtgärd (Swedish) A temporary flexibility procurement concept jointly developed by Svenska kraftnät and Vattenfall Eldistribution (joint intention January 2025) to bridge grid connection delays. When a new connection request cannot be accommodated within the current network, Svk would procure a flexible resource (production, storage, or demand reduction) under longer-term contracts to provide the system capability that the missing network investment would have provided. A pilot ran for Västra Götalandsregionen but concluded (announced March 2026) before any procurement took place: industrial customers’ plans shifted timelines, and in November 2025 Svk gave Vattenfall Eldistribution a new förhandsbesked covering the requested effect through 2035, removing the need. Svk still considers the product specification, working process, and multi-actor coordination experience developed viable for future applications where new connections can’t wait for grid reinforcement. See Svk Transmission Grid Planning › Kapacitetsåtgärder — joint TSO-DSO connection bridge concept. (Svk, “Koncept för kapacitetsåtgärd avslutas – lärdomar ger viktig grund för framtiden”, 2026-03-26)

Kapacitetzon / intressentpool (Swedish) “Capacity zone / interest pool” — new connection process concepts from Svenska kraftnät‘s April 2026 anslutningsprocess review. A kapacitetzon is a defined geographic area with an associated available transmission/connection capacity; Svk’s ambition, presented in May 2026, is to designate the first zone and open an interest pool in spring 2027, with implementation work starting in autumn 2026; its April 2026 report says zones need further work before a first zone can be established. An intressentpool allows potential customers to formally signal connection demand before the application queue opens, including PPA-matching for co-locating producers and consumers. Both concepts require legislation for the formal anvisningssystem (allocation system). The introduction of kapacitetszoner replaces the current first-come-first-served application logic with a capacity-zone framework for queue management. (Source - Elmarknadsrådet Meeting 2 May 2026)

Kinnekulle Energi Swedish DSO operating Götene Flex — one of Sweden’s active local flex markets (from V2023/24). No public market data available. (Source - Sweco Kartläggning av lokala flexibilitetsmarknader (Ei, 2025))

Kalkylränta (Swedish) The allowed rate of return (discount rate) on capital that Ei sets for each DSO as part of the intäktsramsreglering. Calculated using real WACC and CAPM. Raised from 3.39% to 4.53% for local networks between the 2020–2023 and 2024–2027 periods — one of the drivers Konkurrensverket flags in its 2026 competition-law review as inflating capital-cost recovery. From RP5 (2028), Ei moves to an 8-year historical lookback for all parameters, replaces KPIF with KPI as the inflation index, and fixes the debt ratio at 50%. See Source - Ei Inriktning intäktsramar 2028-2031 (2025), Source - Konkurrensverket Analys i Korthet 2026-3 Prisbildningen på Elnätsmarknaden (2026).

Kannibaliseringseffekt (Swedish) — cannibalization effect The phenomenon whereby an increasing volume of weather-dependent generation (wind, solar) increasingly depresses the wholesale price during exactly the hours it produces, eroding its own capture rate as more of the same technology is built. Solar cannibalizes faster than wind because its output concentrates into a narrower window (midday, summer) that saturates quickly; wind’s flatter, more full-load-hour profile spreads the effect more gradually. Quantified empirically for SE4: wind’s capture rate fell from ~80% to ~74% (2024) between 650 MW and 1,300 MW of added offshore wind, while solar’s fell from ~60% to ~54% between 1 GW and 2 GW. See Merit-Order Price Suppression from Weather-Dependent Generation. (Source - Energiforsk Elprispåverkan Vindkraft Skåne SE4 (2026))

Kapacitetsbevarande princip (Swedish) “Capacity-preserving principle” for capital asset valuation: assets are marked to market at nuanskaffningsvärde (replacement cost) using a normvärdes list and sector-specific price index (BKI), rather than at historical acquisition cost. Current approach in Swedish DSO revenue regulation (until RP4/2027). Konkurrensverket‘s 2026 review argues this risks overcompensation because BKI has risen almost twice as fast as general inflation (KPI) since 2012, while capital financing actually competes in a broader capital market that tracks KPI more closely. Being replaced by förmögenhetsbevarande principen from RP5 (2028) to eliminate systematic over/under-return risk caused by index divergence. (Source - Konkurrensverket Analys i Korthet 2026-3 Prisbildningen på Elnätsmarknaden (2026))

BKI — Byggkostnadsindex (Swedish: construction cost index) Statistiska centralbyrån (SCB)‘s sector-specific index tracking construction-sector cost inflation, used by Ei to index the normvärdeslista underlying nuanskaffningsvärde asset valuation (see Kapacitetsbevarande princip). Since 2012, BKI has risen almost twice as fast as general inflation (KPI) — the divergence Konkurrensverket identifies as a structural driver of potential DSO overcompensation under the current capital-valuation method, since capital financing costs track the broader capital market (closer to KPI) rather than construction costs specifically. (Source - Konkurrensverket Analys i Korthet 2026-3 Prisbildningen på Elnätsmarknaden (2026))

Kirchhoff’s laws Physical laws governing current and voltage in electrical circuits. The basis for Flow-Based Capacity Calculation — power follows physical paths, not contracted paths.

Koncernbidrag (Swedish) “Group contribution” — a Swedish tax-law transfer of profit between companies in the same corporate group, deductible for the giver and taxable for the receiver, used to even out taxable results across the group. A recurring theme in DSO scrutiny: Ei R2026:05 found ~80 elnätsföretag per year were net givers (2020–2024), ~20 bn kr cumulative, averaging ~10% of net turnover — evidence of profit extraction from regulated monopoly grids that motivates the intäktsram review. Distinct from ordinary dividends (utdelning) and internal-loan costs (internlån), which the same report also tracks. (Source - Ei R2026-05 Utfallet av Regleringen av Elnätsavgifter (2026))

Kopplingsregim (Swedish) — price-coupling regime The state governing how sensitive a bidding area’s price is to local supply/demand changes in a given hour, determined by whether its interconnectors to neighbouring areas are saturated. Three regimes identified for SE4: coupled to a larger market (low sensitivity, price-taker), isolated (a binding export constraint has decoupled the area — high sensitivity, own balance sets price), and coupled to a same-size neighbour (medium sensitivity). More local weather-dependent generation shifts more hours into the isolated regime, which is why price-suppression effects scale nonlinearly with added volume rather than following one fixed merit-order curve. See Merit-Order Price Suppression from Weather-Dependent Generation. (Source - Energiforsk Elprispåverkan Vindkraft Skåne SE4 (2026))

L

Lastföljning (Swedish) — load-following Operating a power plant’s output to track variations in electricity demand or price, rather than running at a constant (baseload) level. Applied historically to Swedish nuclear reactors in the 1980s–90s (and still practised in France and Germany), typically via control-rod position and, for PWRs, boron concentration in the coolant. Constrained by physical factors — component wear/corrosion, pellet-cladding interaction (PCI), xenon poisoning, and fuel-burnup-dependent minimum load levels — and regulated in Sweden under SvKFS 2005:2, which requires PWR blocks to ramp at 5%/minute and BWR blocks at 10%/minute within the 60–90% rated-power range. Distinct from load-following capability (which most generation types have to some degree) — the term specifically denotes actually operating that way as a matter of course. See Flexibility › Generation-side regulability by technology. (Source - Energimyndigheten ER 2025-20 Flexibilitet Målgruppsanpassad Information (2025))

Leveranssäkerhetsmål (Swedish) “Security-of-supply target” — one of two national electricity-system targets adopted by the Riksdag on 29 May 2024 (alongside the planeringsmål). Requires the Swedish electricity system to have the capability to deliver electricity where demand exists, at the right time, and in sufficient quantity, to the extent it is socioeconomically efficient — with the explicit aim of removing unwarranted obstacles to a market that supports competitive prices. Cited as backdrop for the 2026 prissäkring and anvisningssystem government assignments. See Planeringsmål. (Source - Regeringsuppdrag Prissäkring Elmarknaden (2026))

LFC area — Load-Frequency Control area (SO GL term) A geographic subdivision of a synchronous area in which a TSO implements the frequency restoration process. In the Nordics, each TSO typically operates its own LFC area. (SO GL Art. 3(11), Art. 141)

LFC block — Load-Frequency Control block (SO GL term) One or more LFC areas for which FRR and RR are dimensioned and managed. The Nordic synchronous area typically operates as a single LFC block. (SO GL Art. 3(12), Art. 141)

Limited energy reservoir (SO GL term) An energy storage device (e.g., battery, flywheel) whose capacity limits the duration of FCR provision. In the Nordic synchronous area, FCR providers with limited energy reservoirs must sustain full activation for 15-30 minutes during alert state, and recover within 2 hours. Critical provision for battery participation in Balancing Markets. (SO GL Art. 156(8-13))

Local services (NC DR term) Flexibility services procured by DSOs (or TSOs at distribution level) for congestion management, voltage control, or other local grid needs. The NC DR uses product verification (lower-barrier, ex-post) as the default qualification process for local services, rather than full prequalification.

Local services market See flexibility market. The NC DR uses “local services” as the preferred term for distribution-level flexibility procurement.

LFM-h / LFM-p / LFM-e (NC DR terms) The three product types for local flexibility markets defined in the Network Code on Demand Response, distinguished by procurement horizon:

LFM-h (hour-ahead): spot product for urgent real-time needs; activated up to 1 hour before delivery; energy-only payment (no availability fee).
LFM-p (period-ahead): medium-horizon product; activated 1 day to several days ahead based on planned maintenance or forecast congestion; availability payment optional.
LFM-e (extended): long-horizon availability product; procured weeks to months in advance for structural, predictable congestion; seasonal availability payment required. Swedish market equivalents: SWITCH products map roughly as Direktordrar ≈ LFM-h, Tillgänglighetsordrar ≈ LFM-p, Säsongstillgänglighet ≈ LFM-e. The NC DR allows two procurement models per product type: Model A (DSO sets availability rate, FSPs bid activation price only) and Model B (FSPs bid both availability and activation prices competitively). See LFM Standard Product Design — Model A vs B Recommendations for DSOs, Flexibility Market, Network Code on Demand Response.

LMA — Långsiktig marknadsanalys (Swedish: long-term market analysis) Svenska kraftnät‘s recurring scenario analysis of the Swedish and Northern European electricity system to a long horizon (currently 2050), the principal evidence base for long-term transmission planning. Produced since 2016; the fifth edition, LMA2026, was published 17 June 2026 (four scenarios LF/MM/HP/HF; Swedish 2050 demand 192–333 TWh). Uses Afry’s BID3 model over 44 weather years with investment optimisation. Paired with the KMA (kortsiktig marknadsanalys, ~5-year horizon). See Long-Term Market Analysis. (Source - Svk LMA2026 Långsiktig Marknadsanalys)

Lokalnät (Swedish: local grid) The lowest tier of Sweden’s traditional three-level grid structure — below Svenska kraftnät‘s stamnät (220–400 kV transmission) and regionnät (~40–130 kV, see Regionnät) — carrying power at low and medium voltage directly to end customers, operated by local DSOs (lokalnätsföretag), the most numerous tier by company count (most of Sweden’s 168 DSOs are lokalnät-only). Under EU terminology, lokalnät is unambiguously part of the distribution system. Regulated separately from regionnät under RP5: efficiency incentives use DEA (Data Envelopment Analysis) benchmarking against comparable DSOs, not the MTFP method applied to regionnät (see MTFP). In the NC DR’s multi-level coordination roles, a lokalnät is typically the connecting system operator for a distribution-connected resource, with the regionnät and Svk potentially also acting as impacted system operators for the same activation (see TSO-DSO Coordination — The Central Design Problem › The multi-level DSO complication). See Electric Grid Structure › Sweden’s three levels vs. the EU’s two.

Lösningsneutralitet (Swedish) “Solution neutrality” — the principle that the regulatory framework creates no systematic preference between grid investment (CAPEX) and flexibility procurement (OPEX) as means of managing congestion or meeting grid needs. Achieved under the TOTEX approach in Ei’s RP5 (2028–2031) revenue regulation reform: a DSO that handles congestion by buying flexibility services (opex) scores identically in the benchmarking framework to one that builds new grid (capex). Directly addresses the CAPEX bias identified as a structural barrier to flexibility market development. (Source - Ei Inriktning intäktsramar 2028-2031 (2025))

M

MAPE — Mean Absolute Percentage Error The standard academic accuracy metric for a load forecast: the average, across a set of periods, of the absolute difference between forecast and actual load, expressed as a percentage of actual load. A symmetric, average-weighted loss — it treats every hour’s error equally, regardless of when that error is expensive. This is precisely why a low MAPE is not the same as a good forecast for a flexibility market: settlement economics are asymmetric and concentrated in a few scarce, high-price hours, which MAPE doesn’t weight any differently from a calm night. See STLF for Flexibility Markets — What Counts as Good and How to Achieve It for the full argument.

MARI — Manually Activated Reserves Initiative ENTSO-E platform for cross-border exchange of manually activated frequency restoration reserves (mFRR). Enables participating TSOs to import and export mFRR energy bids pan-European. The Nordic TSOs (Svk + Statnett + Fingrid + Energinet) announced on November 17, 2025 a joint connection target of Q1 2027. Connection will increase mFRR market depth and liquidity. See EAM, Balancing Markets, Nordic Balancing Model. (Source - Svk Balancing Market Outlook 2030 (2024))

Markedsbaseret anskaffelse (Danish) — market-based procurement Denmark’s term for DSO-procured flexibility as an alternative to grid reinforcement — the Danish structural counterpart to Swedish local flexibility markets. First tested via 2025 pilots at Cerius A/S + Radius Elnet A/S (jointly) and, separately, TREFOR El-net, both notified to Forsyningstilsynet under Elforsyningsloven §73a stk. 2 (added by Lov nr. 1677/2024, transposing the EU Electricity Market Directive) and tied to EU Electricity Market Regulation Art. 18. Cerius-Radius tests an availability-fee-plus-activation-payment product (dispatched on 15-minute notice, closer to a Swedish LFM-e product); TREFOR El-net tests a fixed-price standing capacity ceiling the winning bidder must not exceed (closer in shape to a Swedish villkorat avtal). See Congestion Management › Cerius-Radius / TREFOR El-net (Denmark) — flexibility-vs-reinforcement pilot. (Source - Cerius Radius Trefor Markedsbaseret Fleksibilitet Pilot (2025-2026))

Market-based flexibility Flexibility procured through competitive markets with price discovery. The CEP default for both DSO procurement (Directive Art. 32) and TSO redispatching (Regulation Art. 13). Contrast with rules-based flexibility.

MaxUsage (NODES MaxUsage™, “virtual fuse contract”) A NODES-trademarked local flex market product where the FSP and DSO jointly set a ceiling on the FSP’s power demand during specified high-load hours; the FSP is paid for keeping below it, with minimal administration. Validated by counting the proportion of measurement values below the threshold — compensation is for the consistent behavioural change, not a specific activation event. Developed to widen participation, above all for EV charging. Used in Effekthandel Väst (ShortFlex/LongFlex/MaxUsage product family) and in early seasons of Kinnekulle Flex. The value reference is set by analysing historical consumption before contracting; the difference between the reference value and the max value defines the contracted flexibility quantum. Limitation: energy-efficiency or behavioural change between seasons erodes that historical reference (the “normal” drops below the reference value, confounding validation). Mixed record: scaled successfully at Effekthandel Väst (dominant activation product by volume from Dec 2024), but removed from Kinnekulle Flex from 2026–27 — both for reference drift and because time-differentiated power tariffs (EIFS 2022:1) deliver the same implicit load-shifting signal to all users at scale. The fix for the drift is to anchor the cap to a firm contractual level rather than historical consumption (see the internal SWITCH market-design recommendations, §B5). (Source - Effekthandel Väst Produkter och MaxUsage (NODES, 2024), Source - Flexsäsongen i Götene 2024-2025 Sweco, Source - Effekthandel Väst Onboarding Info (2025-26))

MBMA — Meter Before, Meter After A baseline method used in SWITCH where the platform calculates the baseline automatically from the resource’s own metering data, without requiring the FSP to upload a reference plan. One of three approved baseline methods in SWITCH (alongside FSP-provided plan and zero-reference). Removes a key operational burden for FSPs who have reliable metering. (Source - SWITCH User Documentation (2026))

MCP — Market Communication Platform NODES‘s real-time TSO-DSO trade coordination interface. When a buy order is submitted in the flexibility market tool (FMT), the MCP routes a trade approval request to affected system operators before activation. The SO responds with a traffic light signal: Green (no grid impact — proceed), Yellow (impact possible — accepted with conversation; cancellable under strict rules), or Red (critical impact — rejected; negotiation phase opens). Pre-configured node limits can trigger the MCP flow automatically above a threshold. Operationalizes the Network Code on Demand Response‘s temporary limits concept in a real-time platform layer. See NODES › MCP traffic light — TSO-DSO coordination, TSO-DSO Coordination — The Central Design Problem. (Source - NODES FPM Presentation (2026))

Metering point The location where electricity flow is measured. CU registration in the NC DR is tied to metering/connection points.

mFRR — Manual Frequency Restoration Reserve Balancing product activated manually within ~15 minutes. Replaces aFRR for longer imbalances. Bidirectional. See Balancing Markets.

Minimum bid size The smallest quantity a resource can offer in a flexibility or balancing market. A key NC DR debate: 0.1 MW (enables household-scale DER participation) vs 1 MW (favors industrial/aggregated resources). No consensus as of ACER’s 2025 recommendation.

Modbus Communication protocol for real-time metering and device communication. Used in Villkorade Avtal technical requirements.

MTFP — Multifactor productivity Swedish: multifaktorproduktivitet. A productivity measure relating a firm’s total resource use (input — both operating and capital costs) to the benefit it delivers (output). Rising MTFP over time means resources are used more efficiently. Ei will use individual MTFP development over time as the efficiency incentive for regionnätsföretag from RP5 (2028–2031) — chosen over relative DEA benchmarking because regionnät companies are too few for reliable peer comparison, and because a total-cost productivity basis is TOTEX-enabling and lösningsneutral. Contrast with the DEA relative benchmarking used for lokalnät. See RP5 Revenue Cap Methodology (2028–2031) › RP5 efficiency incentive for regionnät — MTFP (announced June 2026). (Source - Ei Effektiviseringsincitament Regionnät MTFP (2026))

N

N-1 criterion The classical deterministic transmission-security standard: the grid must be dimensioned and operated so the loss of any single component (line, transformer, generator) doesn’t cause a customer outage or push voltage/current outside safe limits. Never quantifies risk numerically — a state either passes or fails. The EU is moving toward replacing it with stochastic/probabilistic risk assessment (ACER 2019 decision, GARPUR project, ENTSO-E-led implementation), targeting adoption by all European TSOs by end of 2027. See N-1 Criterion.

Nätavräkning (Swedish) — grid settlement The market-near calculation of how much electricity was withdrawn and injected per grid settlement area (nätavräkningsområde), supplier and balance responsible party, which forms the basis for imbalance settlement (reported to eSett) and final settlement. Distinct from a grid company’s own technical settlement of physical flows and losses. Today each DSO performs it; the proposed central data management tool would take over the market-near part. (Source - Ei R2026-08 Förslag Centralt Datahanteringsverktyg (2026))

Abonnemangspunkt (Swedish) — subscription point The point on Svenska kraftnät’s network where a customer takes out an injection and a withdrawal subscription and where the exchange of power is settled; the term replaces the earlier anslutningspunkt in the usage agreement. Normally each transformer or line connected to a Svk installation is its own subscription point. Used in the Transmission Network Charge. (Source - Svk Tarifföversyn Ny Tariffmodell (2026))

Fördelningsfaktor (Swedish) — distribution factor A factor in Svk’s energy fee from 2027 that compares the cost of procuring the network losses in the price area where they arise with the cost in the price area where the subscription point sits; in the 2027 price list it is 0.9 or 1.1. It is phased in (half effect in 2027, in full from 2028). See Transmission Network Charge. (Source - Svk Tarifföversyn Ny Tariffmodell (2026))

Nätpaketet (Swedish) — EU network package Informal name for the European Commission’s legislative proposal on electricity network planning and investment, published December 2025. Under Council negotiation from December 2025 onward. Key elements as understood from Swedish political debate: (1) proposed restrictions on how member states may use flaskhalsinkomster (congestion revenues); (2) proposed centralization of electricity system planning at EU level. Sweden has been strongly critical on both counts. As of May 2026, Sweden’s government ordered Svk to pause three planned HVDC interconnector projects (Konti-Skan Connect, Aurora Line 2, Fenno-Skan 3) as leverage in the negotiations. See Svenska kraftnät, flaskhalsinkomster. (Source - Svk Utlandskablar Uppdrag Reviderad Investeringsplan (2026))

Nationella villkor (Swedish — “national terms and conditions”) The binding national rules that Sweden’s ~170 DSOs and Svenska kraftnät must jointly develop under the Network Code on Demand Response (NC DR). Once adopted, nationella villkor have the same legal status as national föreskrifter (regulatory provisions). The NC DR requires all DSOs and Svk to submit a joint proposal for a national development process to Ei within 3 months of the regulation entering into force; Ei then has 2 months to approve the process proposal. Subject areas span approximately 7 domains, including SP qualification, baselines, FIS implementation, TSO-DSO coordination, local market rules, DNDPs, and energy storage. The development of nationella villkor is unprecedented in Sweden — DSOs have never previously had a statutory role in drafting binding sector regulation. Energiföretagen Sverige‘s Eldistributionsrådet proposed a hybrid governance model (open to all DSOs, not just Energiföretagen members) in April 2024. See Network Code on Demand Response, Energiföretagen Sverige. (Source - Energiföretagen NC DR National Conditions Webinar (2024))

Nätkoncession (Swedish) — grid concession / network licence The licence from Ei required to build and operate an electricity grid in Sweden. Two forms: nätkoncession för område (area concession) — the right to build and operate a grid within a defined geographic area, used for distribution networks; and nätkoncession för linje (line concession) — granted line-by-line for individual higher-voltage connections. Practice and förarbeten set the area-concession voltage ceiling at 110 kV; higher-voltage lines normally require a line concession. In a 2026-06-22 decision (ärende 2025-103405), Ei granted E.ON Energidistribution an area concession at 82–145 kV in the Malmö region — exceeding the 110 kV norm — citing special circumstances (a delimited metropolitan area, mainly developed land, build-out only with mark- och sjökablar) and the goal of faster, more cost-effective expansion than per-line prövning. See Ei, Distribution System Operator. (Source - Ei Beslut Nätkoncession 145 kV Malmö (2026))

Natural monopoly An industry where single-provider operation is most efficient due to infrastructure costs. Both transmission and distribution are natural monopolies, which is why they are regulated and unbundled from competitive activities. See Natural Monopoly.

NC DR — Network Code on Demand Response Forthcoming EU regulation establishing binding rules for demand response, energy storage, distributed generation, and demand curtailment market participation. See Network Code on Demand Response.

NODES Flexibility market platform developed by NODES AS (Norwegian company, Lysaker). One of two active platforms in the Swedish flexibility market — the other being SWITCH. Used by sthlmflex (closed), JämtFlex (closed), and Effekthandel Väst (active). As an independent third-party platform, NODES is the natural choice for multi-DSO markets requiring a neutral operator. See NODES. (Source - Sweco Kartläggning av lokala flexibilitetsmarknader (Ei, 2025))

Non-fossil flexibility Flexibility provided by demand response, energy storage, and dispatchable renewable generation — as distinguished from fossil-fuel-based flexibility (gas peakers, diesel backup). The EMD Reform 2024 introduces an indicative national objective for non-fossil flexibility: each member state must define this objective within 6 months of completing their first FNA (Art. 19f, Regulation 2024/1747). Where investment is insufficient, member states may apply capacity payment support schemes for non-fossil flexibility resources (Arts. 19g–h). For Sweden, the national objective would be due January 2027 (assuming first FNA approved July 2026). (Regulation 2019/943, Arts. 19f–19h as inserted by Regulation 2024/1747; Source - Electricity Market Design Reform Regulation (EU 2024-1747))

NordSyd Svenska kraftnät‘s flagship initiative to increase north-south transmission capacity through four parallel reinforcement branches (Uppsala, Västerås, Karlstad, Hallsberg). See NordSyd.

Norrmodellen A working method and collaboration model for municipal-level mapping of current and future power and energy needs (both withdrawal/uttag and injection/inmatning) in Norrbotten. Administered by Länsstyrelsen Norrbotten under the AGON (Accelererad Grön Omställning) umbrella. Participants: regional DSOs (Luleå Energi, Piteå Energi, Boden Energi, Vattenfall Eldistribution) and large industrial customers (LKAB, SSAB, Stegra, Boliden, etc.) and Svenska kraftnät. Data is aggregated at municipality and county level. Updated on a regular frequency; high precision for the nearest 5–8 years. The model emerged from the need to create a common factual picture of the enormous industrial electrification investments planned for SE1 — a prerequisite for coherent grid planning and financing decisions. (Source - Nationell Dialog Flexibilitet Nätkapacitet 12 Maj 2026)

NTC — Net Transfer Capacity Previous method for cross-zonal capacity calculation based on simplified bilateral exchange limits. Replaced by Flow-Based Capacity Calculation in the Nordics (October 2024).

Nuanskaffningsvärde (NUAV) (Swedish) — current replacement cost The capital-base valuation method used in Swedish DSO revenue-cap regulation: assets are valued at what an equivalent asset would cost to build today, age-adjusted, rather than at historical purchase/construction cost. Rationale: many Swedish grid assets are decades old and heavily depreciated in the accounts, so historical book value understates both capital employed and the true cost of maintaining/renewing the grid — using NUAV instead avoids the resulting overstatement of apparent return-on-capital. RP5 (2028–2031) shifts the underlying principle from kapacitetsbevarande to förmögenhetsbevarande; see Swedish DSO Landscape › Regulatory note — capital-base valuation as the cross-country differentiator and Swedish DSO Landscape › Reading the margin figures correctly.

O

Obalansanalys (Swedish) An analysis of imbalances in the electricity system — specifically the volume and pattern of BRP (balansansvarig) imbalances compared to their notified production and consumption plans. Svenska kraftnät presented a multi-year obalansanalys at the November 2024 Elmarknadsrådet showing that imbalances in Sweden and the Nordics have increased significantly over the past ten years, driven primarily by the 800% increase in average hourly wind production. SE2 shows the largest growth. Key structural factors: 90% of electricity trading occurs 12–36 hours before delivery (day-ahead); the balancing window closes 45 minutes before the delivery hour, leaving BRPs limited time to correct positions. (Source - Elmarknadsrådet Meetings 3 and 4 2024 (Sep-Nov))

Observability area / Observerbarhetsområde (Swedish) (NC DR term) The geographical scope a DSO defines for monitoring grid conditions — its own network plus relevant adjacent segments. Used for congestion forecasting and coordination with TSOs and neighboring DSOs.

OCPP — Open Charge Point Protocol Communication protocol for EV charging infrastructure — governs communication between an EV charger (charge point) and its backend management system. OCPP 2.1 is the version required for Vehicle-to-Grid: it adds bidirectional charging support, enabling aggregation platforms to control and monitor V2G discharge sessions. Relevant for EV-based Aggregation and Demand Response. Compare with ISO 15118-20 (vehicle↔charger communication) — OCPP covers the charger↔backend layer. (Source - Power Circle V2X Synthesis 2024)

Ö-drift (Swedish) / Island operation Operating a grid section disconnected from the main transmission or distribution network, sustained by local generation and storage. Relevant as both a technical reliability tool (automatically triggered by cable faults) and a crisis preparedness instrument (intentional ö-drift planning for severe outages). Svenska kraftnät defines four levels: (1) elberedskapsö-drift — planned, crisis/war preparedness; (2) planerad ö-drift — planned maintenance isolation; (3) oplanerad ö-drift — fault-triggered, reconnect when fault cleared; (4) oavsiktlig ö-drift — unintentional, requires immediate detection and reconnection (islanding protection). The binding technical constraint is black start capability: the ability to re-energize a de-energized network segment without external power. Swedish operational examples: Arholma (Vattenfall Eldistribution) and Simris (E.ON Energidistribution). See Island Operation for full taxonomy, protection engineering, cybersecurity, case studies. (Source - Svk Om Ö-drift (2025))

Ombud (Swedish) — aFRR intermediary A licensed intermediary that submits aFRR bids to Svenska kraftnät‘s aFRR market on behalf of an aggregator or other market participant that is not itself a qualified BSP. The ombud mechanism allows entities like CheckWatt to access the Nordic aFRR market without holding full BSP qualification. Svk opened ombud access to third-party aggregators on January 15, 2025 as part of the aFRR cross-BRP aggregation rollout. Distinct from the BSP/BRP split — ombud is a transitional mechanism, not full BSP status. See Aggregation, Balancing Markets. (Source - CheckWatt Website (2025-2026))

OpenADR — Open Automated Demand Response Communication protocol for automated Demand Response signal exchange between utilities/DSOs and customer energy management systems. Standardized as IEC 62746-10-1; maintained by the OpenADR Alliance. DSO = VTN (Virtual Top Node, server); customer/CPO = VEN (Virtual End Node, client). Version 3.0.1 recommended for new Swedish implementations (REST/JSON; more modern than the older SOAP/XML 2.0b). Industry-recommended for Swedish Villkorade Avtal communication by Energiföretagen Sverige since October 2023 (voluntary). Two live production variants exist as of April 2025: E.ON’s (CONSUMPTION_POWER_LIMIT, PT15M, dynamic KW limits, real-time metering) and Ellevio’s (SIMPLE Curtail/Restore, PT20M, pre-agreed static limits). See OpenADR.

Öppet kundgränssnitt (Swedish) — open customer interface The standardised interface on a Swedish smart meter (HAN-port type, based on a relevant European standard) through which a customer can access their own meter values in near real time — enabling third-party realtidsmätare, in-home displays, and automated steering services to read consumption directly. Required by förordning (1999:716) and the mätföreskrifterna (EIFS 2025:1). From 1 January 2027, EIFS 2026:8 (4 kap. 4 §) requires every DSO to publish information about this interface and which dataprotokoll it supports, explain its use, and show on mina sidor whether a customer’s interface is active — a duty that followed Ei’s spring-2025 riktad tillsyn finding that missing protocol information was limiting consumer choice and undermining the open-standard requirement. Publishing supported protocols (rather than naming brands) preserves DSO neutrality. Distinct from a behind-the-meter DMD (Art. 7b): the öppet kundgränssnitt reads the connection-point meter, not an individual circuit/appliance. See Submetering, Source - EIFS 2026-8 Nätföretags Information till Elanvändare (2026).

Överrullning (Swedish) The revenue-cap true-up mechanism in ellagen: if a DSO’s actual revenue during a tillsynsperiod diverges from its intäktsram, the following period’s cap is adjusted to compensate. Revenue exceeding the cap by more than 5% obliges Ei to reduce the next period’s cap by an överdebiteringstillägg (overcharge surcharge); a shortfall may be carried forward, but only to the single next period, not further. The one-period limit has been contested from both directions: a 2019 Kammarrätten ruling permitting multi-period accumulation was blocked by Prop. 2019/20:53 (with the blocked deficit rerouted into the separate särskilt investeringsutrymme law), SOU 2023:64’s proposal to extend it to two periods was rejected by Prop. 2025/26:26, and Dir. 2026:83 (reporting 24 November 2027) now asks whether it should be restricted further. See RP5 Revenue Cap Methodology (2028–2031) › Dir. 2026:83 — a further revenue-cap inquiry (decided July 2026), Konkurrensverket. (Source - Konkurrensverket Analys i Korthet 2026-3 Prisbildningen på Elnätsmarknaden (2026), Source - Överrullning av Intäkter Energiföretagen (2019-2023))

Överbelastningsreserv (Swedish) A reserve instrument procured by Svenska kraftnät (procured November 2024, contracts from January 2025) to replace the störningsreserv (disturbance reserve) when its contracts expired. Unlike the störningsreserv, which covered mainly production-side emergency capacity, the överbelastningsreserv was procured through an open competition accepting both production resources and consumption resources, and also included the capability systemdriftskompensation. It is a grid-level instrument aimed at handling local overload situations rather than system-wide scarcity (which is the role of the Strategisk Reserv). (Source - Elmarknadsrådet Meetings 3 and 4 2024 (Sep-Nov))

P

PDIRD-E — Plano de Desenvolvimento e Investimento das Redes de Distribuição de Energia Elétrica (Portuguese) “Distribution Network Development and Investment Plan for Electricity” — Portugal’s equivalent of Sweden’s DNDP (nätutvecklingsplan). Produced by E-Redes every 5 years (quinquennial), with biennial updates. Reviewed by ERSE (NRA) via binding opinion; approved by Council of Ministers resolution. Legal basis: Decreto-Lei 15/2022 (transposing Directive 2019/944). PDIRD-E 2024 covers 2026–2030; total investment €1,607.6M. Portugal is identified as the most advanced EU country for DNDP flexibility quantification by ACER/CEER. (Source - ERSE Parecer PDIRD-E 2024, Distribution Network Development Plan)

PCI — Project of Common Interest Cross-border energy infrastructure project selected under the EU TEN-E Regulation as qualifying for streamlined permitting, accelerated review, and potential CEF (Connecting Europe Facility) co-funding. PCIs are identified through the TYNDP (Ten-Year Network Development Plan) process and listed in a Union list updated every two years. Since 2022, the TEN-E framework also covers PMIs (Projects of Mutual Interest — with third countries), offshore grid projects, smart grids, hydrogen, and electrolysers. The 2023 Union list contains 166 PCIs/PMIs including 68 electricity projects. The European Grids Package (COM/2025/1005) proposes to expand PCI eligibility to internal reinforcements (not only cross-border) and non-wire solutions, and to simplify the reapplication process for mature PCIs. (Source - EU Grid Action Plan COM2023-757, Source - European Grids Package COM2025-1005)

Peak-shaving product A market-based demand response product activated during declared EU/regional electricity price crises (Art. 7a, Regulation 2024/1747). Member states may instruct system operators to procure peak-shaving from demand-side resources during a Council-declared crisis; minimum bid size ≤100 kW (including aggregation); procurement via competitive bidding; activation in or before the day-ahead timeframe; no fossil generation behind the meter. Defined in Regulation 2019/943 Art. 2(73–74) as amended. (Regulation 2024/1747, Art. 7a; Source - Electricity Market Design Reform Regulation (EU 2024-1747))

Peak shaving Reducing peak demand through storage discharge or load reduction. Reduces congestion and defers grid reinforcement.

PICASSO — Platform for the International Coordination of Automated Frequency Restoration and Stable System Operation ENTSO-E platform for cross-border exchange of automatically activated frequency restoration reserves (aFRR). Enables participating TSOs to import and export aFRR energy bids pan-European. Nordic connection timeline: Energinet (Denmark) connected October 2024, Fingrid (Finland) March 2025. Svenska kraftnät (Sweden) and Statnett (Norway) target Q4 2027 (provisional — Svk notes the date carries “technical and market-related dependencies”). Each country connects independently — no coordinated Nordic date, unlike MARI. Connection is expected to import Norwegian aFRR upward capacity into Sweden, potentially reducing the structural aFRR price asymmetry (up prices lower than down prices due to Norwegian imports). See Balancing Markets, Nordic Balancing Model. (Source - Svk Balancing Market Outlook 2030 (2024), Source - Svk PICASSO Anslutningsdatum (2025))

Planeringsmål (Swedish) “Planning target” — one of two national electricity-system targets adopted by the Riksdag on 29 May 2024 (alongside the leveranssäkerhetsmål). Requires the electricity system to be planned to meet demand of at least 300 TWh by 2045, with need broken down by geographic area and tracked at checkpoints in 2030, 2035, 2040, and 2045, starting 2030. Distinct from Svenska kraftnät‘s planeringsscenario (a single reference scenario for TSO planning, below) — the planeringsmål is the Riksdag-level demand target the planeringsscenario is built to serve. (Source - Regeringsuppdrag Prissäkring Elmarknaden (2026))

Planeringsscenario (Swedish) “Planning scenario” — a single, energy-policy-aligned scenario that Svenska kraftnät will adopt as the basis for national electricity-system planning under its expanded planning mandate (instruction in force 1 August 2025), complemented by alternative development paths for risk and uncertainty. Distinct from the multiple exploratory scenarios in the LMA: LMA2026 was not built around a planeringsscenario, though Medel mixat (MM) is judged closest. Work on the full planeringsscenario begins autumn 2026. (Source - Svk LMA2026 Långsiktig Marknadsanalys)

PPA — Power Purchase Agreement EU legal definition (Regulation 2024/1747, Art. 2(77)): “A contract under which a natural or legal person agrees to purchase electricity from an electricity producer on a market basis.” Long-term bilateral electricity supply contract between a renewable generator and a buyer (consumer, trader, or other entity), fixing price, quantity, duration, and risk allocation outside the standard spot market. Main types: on-site PPA (direct delivery behind meter), off-site PPA (via public grid, balance group settlement), sleeved PPA (off-site with energy service provider intermediary), and virtual/synthetic PPA (financial only, using a Contract for Difference structure). Typical duration 10–15 years. EU member states must promote PPAs and ensure buyer-default guarantee schemes under Art. 19a of Regulation 2024/1747. See Power Purchase Agreement. (Source - Electricity Market Design Reform Regulation (EU 2024-1747), Source - PPAs Explained (Next Kraftwerke))

Procuring system operator (NC DR term) The system operator that actively procures balancing or local services from a service provider. Responsible for: running the market or tendering process, bid selection, activation, settlement, and publication of market results. Must act non-discriminatorily and maintain IT solutions for the full procurement process. Must not share preferential or commercially sensitive information with affiliated companies. Distinct from the connecting system operator (where the resource is connected) and the impacted system operator (whose grid may be affected). (Source - NC DR Amended Text (ACER Recommendation 01-2025 Annex 1))

Prequalification (NC DR term) Standard ex-ante verification that a resource meets the technical requirements for a specific balancing or flexibility product. Distinguished from product verification (lighter, ex-post) used as the default for local services.

Prissäkring (Swedish) “Price-hedging” — securing a known electricity price in advance rather than being exposed to volatile spot-market prices, typically via long-term contracts such as PPAs (elköpsavtal). The subject of a June 2026 joint government assignment to Ei and Svenska kraftnät, which specifically examines whether long-term price-hedging instruments could be used to let large new electricity users connect faster, conditional on bringing matching new fossil-free production. See Leveranssäkerhetsmål, Planeringsmål. (Source - Regeringsuppdrag Prissäkring Elmarknaden (2026))

Product verification (NC DR term) Lower-barrier, ex-post process for confirming a resource meets product requirements. The default for local services in the NC DR (Art. 19); full product prequalification (ex-ante) applies only when SPU/SPG capacity exceeds a voltage-level threshold defined in national T&C. From application confirmation, the resource receives temporary qualification allowing immediate market participation pending the verification result. Where the SPU/SPG consists entirely of small CUs (≤50 kW) or identical already-prequalified CUs, the process is simplified. (Source - NC DR Amended Text (ACER Recommendation 01-2025 Annex 1))

Punktlast (Swedish — “point load” or “point connection”) A large individual consumer, producer, or mixed installation that connects at a single point in the distribution network and creates concentrated demand or supply. In DNDP planning, punktlaster are distinguished from the organic, distributed growth of residential and small-commercial load. Key characteristics: (1) individually significant MW scale that can stress a feeder or substation; (2) high uncertainty — feasibility of connection is often unclear at plan publication time, so many DSOs exclude them from forecasts; (3) short lead time relative to grid investment — a punktlast can materialize faster than grid reinforcement can be built. Common examples in Swedish NUPs: large battery storage, EV fleet charging depots, data centers, hydrogen electrolysers, industrial electrification projects, and solar parks. Because punktlaster often exceed available grid capacity, they are the primary driver of villkorade avtal (conditional connections) and the main source of uncertainty in DNDP aggregate figures. See Distribution Network Development Plan, Villkorade Avtal, Source - Nätutvecklingsplaner i Skåne 2025-2034 Region Skåne (2025).

Q

Quantification Aggregator (IA DR role) The party responsible for aggregating metering data from multiple Controllable Units to produce consolidated flexibility quantification figures for settlement purposes. One of the new roles introduced by the IA DR (Implementing Act on Demand Response) in Phase 2. Works alongside the Quantification Responsible (who holds accountability for the final quantification) and the Baseline Calculator. Handles the data aggregation layer in the baseline/quantification process chain. (Source - Svk IA DR Webinar Part 1 (2025))

R

Restore product (FIRMe term) A local flexibility market product in E-Redes’ FIRMe programme (Portugal) for post-fault network restoration — activated in extraordinary situations associated with restoring the network after unexpected events. One of FIRMe’s three products alongside Dynamic (planned maintenance) and Secure (congestion management). The Restore product addresses the grid restoration use case that no Swedish local flexibility market product currently covers; it may be relevant as a product extension for Swedish DSOs facing complex fault scenarios. (Source - E-Redes FIRMe Programme)

Reserve connecting DSO (SO GL term) The DSO responsible for the distribution network to which a reserve providing unit or group is connected. Has the right to set limits or exclude reserve delivery based on technical reasons (e.g., geographical location, grid constraints). The NC DR extends this concept through the observability area and TSO-DSO coordination framework. (SO GL Art. 3(149), Art. 182)

Reserve providing group (SO GL term) An aggregation of power generating modules, demand units, and/or reserve providing units connected to more than one connection point, fulfilling requirements to provide FCR, FRR, or RR. Precursor to the NC DR’s Service Providing Group (SPG) concept. (SO GL Art. 3(11))

Reserve providing unit (SO GL term) A single or aggregation of power generating modules and/or demand units connected to a common connection point, fulfilling requirements to provide FCR, FRR, or RR. Precursor to the NC DR’s Service Providing Unit (SPU). (SO GL Art. 3(10))

Redispatching (Swedish: omdirigering) Adjusting generation or load to relieve grid congestion after the market has cleared. The CEP requires market-based redispatching as the default (Regulation Art. 13). Non-market-based redispatching (including Villkorade Avtal) requires Art. 13(3) exceptions to be met. Ei classifies villkorade avtal as non-market-based redispatching; Ei2025:01 adds that non-market activation requires a fresh assessment after gate closure for each operating quarter, after market-based alternatives are exhausted. (Source - Ei Villkorade avtal (2023), Source - Ei Ställningstagande Ei2025-01 Villkorade avtal (2025))

Regionnät (Swedish: regional grid) The middle tier of Sweden’s traditional three-level grid structure — sitting between Svenska kraftnät‘s stamnät (220–400 kV transmission) and lokalnät (local distribution) — carrying power at roughly 40–130 kV. Operated by regional DSOs (regionnätsföretag), of which E.ON, Vattenfall Eldistribution, and Ellevio own the majority; Sweden’s regionnät sits within the international subtransmission band (typically 34.5–138 kV worldwide, no fixed cutoff — Source - EEP Basics of Subtransmission Systems (web)) and is not structurally unusual by European standards: 19 of 27 EU member states have DSOs operating at 110 kV or higher. Regional DSOs face a distinct coordination problem — they connect to Svk’s stamnät through subscription levels (abonnemang) at TSO-DSO interface substations, and exceeding a subscription incurs a penalty, creating a direct incentive to procure local flexibility (see TSO-DSO Coordination — The Central Design Problem). Under EU terminology, regionnät is legally part of the distribution system, not transmission — a July 2026 government inquiry (Dir. 2026:83) is investigating whether Sweden should collapse its three-level structure to the EU’s two, including whether Svk should take over regionnät assets. Regulated separately from lokalnät under RP5: efficiency incentives use MTFP, not DEA benchmarking (see MTFP). See Electric Grid Structure › Sweden’s three levels vs. the EU’s two.

RES — Renewable Energy Sources Standard EU/Nordic shorthand for renewable-source electricity generation (chiefly wind and solar). Central to FNA/FNAM terminology: RES integration need (FNAM Art. 8) is the flexibility required to reduce curtailment and meet a member state’s renewables target; RES spill is curtailed/wasted renewable output when the grid or system cannot absorb it — in Sweden’s FNA 2026, rising from ~3.66 TWh (2030) to ~5.22 TWh (2035) after DSO-data fine-tuning, occurring in over half the year’s hours and driven by recurring wind-heavy, low-demand periods rather than extreme events alone. A DSO’s RES-linked share of downward flexibility need (nedreglering) is separately reported via the FNAM Tabell 15 template — 52% nationally in 2030, rising to 71% by 2035. See Flexibility Need Assessment › FNA 2026 results (Svk final report, 29 June 2026). (Source - Svk FNA 2026 Slutrapport (2026))

Rogowski coil A flexible current-sensing coil wrapped around a conductor to measure AC current without breaking the circuit — no iron core, so it stays linear at high currents and is cheap and easy to retrofit compared to a conventional current transformer. In a Swedish grid-data context it’s the practical entry point for submetering: a low-cost way to add current/voltage sensing at a nätstation or behind-the-meter circuit where SCADA-grade instrumentation isn’t justified. Needs an integrator circuit to convert its output (proportional to the rate of change of current, not current itself) into a usable measurement.

RPU / RPG — Reserve Providing Unit / Reserve Providing Group Abbreviations used in the SO GL and in ACER’s FRR prequalification decisions for a unit or a group providing FCR, FRR or RR; the full definitions are under reserve providing unit and reserve providing group. Below them sits the controllable unit (CU), the individual asset such as a battery or heat pump. The distinction matters in ACER Decisions 12 and 13/2026: prequalification and re-prequalification apply to RPUs and RPGs, “small” and “identical” RPUs and RPGs can be tested in a simplified way, and the new switching process between BSPs covers RPUs only. (Source - ACER Decisions 12 and 13-2026 FRR Implementation Frameworks Third Amendment (2026))

Rundstyrning (Swedish) Ripple control — a largely phased-out Swedish DSO mechanism that sent a kHz signal on top of the 50 Hz supply to remotely switch water boilers, street lamps, and controllable loads. Installed by many Swedish DSOs in the mid-1990s; could curtail up to 7–8% of peak load in smaller DSO networks. Monthly tariff discount incentivized customer participation. Phased out ~2000 in the absence of delivery responsibility after deregulation. Represents an earlier, pre-digital form of demand flexibility — now being “reinvented in a more digital and market-oriented way.” See Rundstyrning for full treatment. (Source - CoordiNet D4.7.2 Swedish Demonstration (2022))

Realiseringstid (Swedish) “Realization time” — the period over which identified efficiency potentials in DSO operations are assumed to be realised in the Swedish revenue cap regulation. Set at 8 years (two four-year supervisory periods) for both RP4 and RP5. A longer realization time reduces short-term pressure on DSOs (efficiency can be achieved gradually) but means customers bear the cost of identified inefficiency for longer. The 8-year level reflects that many grid efficiency improvements require investment in long-lived capital assets. (Source - Ei Effektiviseringsincitament Webb (2026-05-12))

Revenue cap regulation See intäktsramsreglering.

Rules-based flexibility Flexibility mandated or incentivized through regulation, tariff design, grid codes, or contractual obligations (as opposed to market transactions). Examples: dynamic network tariffs, Villkorade Avtal, grid code requirements for DER voltage support. Contrast with market-based flexibility.

S

Sällanköpsmarknad (Swedish) “Rare-purchase market” — Ei’s characterization of Swedish local Flexibility Markets, where congestion events are infrequent and geographically limited, resulting in low liquidity, few activations, and weak revenue for providers. A fundamental structural challenge for distribution-level flexibility markets. (Source - Ei Flexibility in Distribution Grids (2023))

Sammanlagring (Swedish) — coincidence / diversity aggregation The fact that individual customers’ peak demands do not all occur at the same moment, so the aggregate peak on a feeder, nätstation, or gränspunkt is far below the sum of individual peaks. Central to capacity assessment (faktisk belastning) and to judging tariff effectiveness: an effektavgift that targets each customer’s own monthly peak can change behaviour a lot yet do little for the coincident feeder peak that actually drives reinforcement — Energiforsk’s 2026 simulation found exactly this “limited grid benefit once sammanlagring is accounted for.” See Demand Response, The Signal Stack — Price Signal Collisions at the Customer DER. (Source - Energiforsk 2026-1197 Konkurrensen om Efterfrågeflexibilitet Simulering (2026))

Särskilt investeringsutrymme (Swedish) — special investment headroom Lag (2021:311) om särskilt investeringsutrymme för elnätsverksamhet, in force 1 June 2021. Lets a DSO with unused revenue-cap headroom from the 2012–2015 tillsynsperiod — headroom that ordinary överrullning could not carry past 2016–2019 — apply for a “särskilt investeringsutrymme” matching that historical deficit, usable to raise its 2020–2023 and/or 2024–2027 revenue cap by an investment-linked amount. Conditions: investment must exceed 1% of the DSO’s capital base as of 2019-12-31 (brytpunkt); above that threshold, 75% of each invested krona may draw on the historical deficit, 25% must be financed otherwise; new-connection fees don’t count toward the qualifying investment; the cap increase for a given accounting unit cannot exceed that unit’s actual investment in the period. Enacted as the negotiated resolution to the 2019 överrullning block — Energiföretagen accepted the block in exchange for this route. A 2023 inquiry (SOU 2023:64) proposed repealing it as a Tysklandsdomen independence risk; Prop. 2025/26:26 (October 2025) rejected that, finding the law governs use of a historical deficit, not Ei’s tariff-method-setting authority, and therefore does not implicate NRA independence. (Source - Överrullning av Intäkter Energiföretagen (2019-2023), Source - Prop. 2025-26-26 Regelverket för Framtidens El- och Gasnät (2025))

Självreglering (Swedish) “Self-regulation” — a concept in Nordic balancing markets where a Balance Responsible Party (BRP) deliberately maintains an imbalance in the opposite direction to the current system-wide imbalance — for example, going short when the system is long — to help reduce the total system imbalance. Distinct from normal BRP behavior (minimizing one’s own portfolio imbalance) and from BSP provision of balancing reserves.

Currently not allowed in Sweden. All other Nordic countries (Finland, Denmark, Norway) and several other European countries (Netherlands, Belgium) permit it. Svenska kraftnät was formally evaluating whether to allow self-regulation as of February 2026. Prerequisites identified: accurate real-time balance data published to market; resources with sufficiently fast activation; correct incentives (aligned with system direction); complementary to, not substituting for, TSO balancing. Risk: many actors responding simultaneously to the same published data could create oscillations, particularly with fast-acting battery resources. (Source - Elmarknadsrådet Meeting 1 February 2026)

Säsongstillgänglighet (ST) “Seasonal availability” — the longest-horizon product in SWITCH, procured months before the market season. The DSO specifies peak hours (e.g., weekdays 07–11 and 16–20, November–March) and a total volume need; FSPs bid an activation price; lowest price wins. A schedule is created and flexibilitet orders are generated automatically throughout the season. FSPs receive availability payment regardless of whether activation occurs; activation triggers additional payment. Clearing happens W-2; activation day-ahead (D-1 09:30–10:30) or intraday (H-2). See SWITCH › Products. (Source - SWITCH User Documentation (2026))

SAIDI / SAIFI / MAIFI — continuity-of-supply indicators Standard distribution-grid reliability metrics: SAIDI (System Average Interruption Duration Index) measures average outage duration per customer per year; SAIFI (System Average Interruption Frequency Index) measures average number of long interruptions per customer per year; MAIFI (Momentary Average Interruption Frequency Index) measures short interruptions. CEER has published seven editions of a benchmarking report on these since 2001 (7th edition, 2022), but notes the indicators are not fully harmonised across Europe: countries vary in weighting methods, inclusion/exclusion of interruption causes, definitions of “exceptional events,” and whether multiple subsequent interruptions are counted separately or aggregated — affecting cross-country comparability even where the same indicator names are used. Proposed as core output indicators (dimension 3, continuity of supply and resilience) in CEER’s 2026 smart-grid performance framework. See Digitalization and Smart Grid. (Source - CEER Electricity Smart Grid Performance Indicators (2026))

SCADA — Supervisory Control and Data Acquisition System for remote monitoring and control of grid infrastructure (substations, switches, equipment).

SE1, SE2, SE3, SE4 Sweden’s four Bidding Areas, from north (SE1) to south (SE4). Structural surplus in SE1–SE2 (hydro, wind); structural deficit in SE3–SE4 (population, industry).

Service Provider (SP) (NC DR term) A qualified market participant that supplies flexibility services (local or balancing) from one or more SPUs or SPGs. Must be registered in the flexibility register.

SP Module Operator (IA DR role) The party responsible for operating the SP-module of the FIS (Flexibility Information System). Manages SP and SPG registration data and the associated data exchanges (Processes 9–15 in the IA DR Phase 1 scope). Counterpart to the CU Module Operator on the service-provider side of the FIS architecture. One of the new role types introduced by the IA DR not present in the NC DR itself. (Source - Svk IA DR Webinar Part 1 (2025))

Service Providing Group (SPG) (NC DR term) An aggregation of Controllable Units across multiple connection points within a scheduling area. The NC DR’s formal mechanism for Aggregation — the regulatory equivalent of a Virtual Power Plant.

Service Providing Unit (SPU) (NC DR term) A single Controllable Unit or ensemble of CUs at one connection point that participates in a market as a unit.

Settlement-grade submetering / Indicative submetering Two quality tiers for dedicated measurement device (DMD) data. Settlement-grade: meets calibration and accuracy standards for use in formal billing, invoicing, and market settlement; requires independent certification, tamper detection, and full audit trail. Indicative: sufficient for operational decisions, DSO observability, and baseline calculation, but not for direct billing; lower cost, easier to deploy.

Smart grid indicators (SGIs) / smart electricity grid indicators Metrics of how far smart and innovative grid technologies are deployed and used in distribution and transmission networks. In the Commission’s July 2026 proposal to amend the Electricity Regulation (COM(2026) 600, Art. 18a), ACER would recommend them and report on them every three years and the Commission could adopt them by implementing act; the EU DSO Entity argues they measure technology adoption, not cost-efficiency, and should stay national (DSO Entity’s reaction). CEER’s 14 output indicators and Ei’s 13 in R2026:02 are the existing national and EU-level sets; see Digitalization and Smart Grid.

Most flexibility service applications — including baseline calculation for activation settlement, per-DER attribution in mixed-asset portfolios, and DSO grid observability — require only indicative-grade submetering. Requiring settlement-grade for all applications is a disproportionate deployment barrier identified by the BeFlexible project survey. The distinction is critical for regulatory design: NC DR T&C development should specify which applications require which tier to avoid over-specification. See Submetering, Dedicated measurement device (DMD). (Source - Submetering for Flexibility Services Comillas (2024))

70% rule At least 70% of thermal capacity on critical network elements must be made available for cross-zonal trade. See Flow-Based Capacity Calculation, Bidding Areas. (Regulation Art. 16(8))

ShortFlex / ShortFlex Availability / LongFlex Product family used on sthlmflex (and conceptually parallel to SWITCH product categories):

ShortFlex (fria bud): spot energy bids, pay-as-bid, activated day-ahead or intraday (T−2 gate closure), no availability fee
ShortFlex Availability: medium-term product introduced in sthlmflex season 3 (V2022/23), replacing VeckoFlex. DSOs announce specific hours (1–5 days ahead, based on forecasts) when availability is needed; FSPs bid to be available for those hours. Availability fee ~2,000 kr/MWh (capped at 1 MWh/h per FSP), activation max 2,800 kr/MWh. At least 160 availability hours/season guaranteed by the buying DSOs. Also used in Effekthandel Väst (NODES)
LongFlex: multi-season availability contract (1–3 winters); triggered at ≤−5°C (SMHI forecast, day before), within peak windows 07:00–11:00 and 17:00–21:00; two-part payment (availability + activation) All products: 0.1 MW minimum bid, 0.01 MW granularity, 60-minute uthållighet, pay-as-bid pricing, delivery tolerance of 80% for full payment (linear reduction to zero at 40%). (Source - sthlmflex säsong 3 (2022-2023))

Snitt (Swedish) See intersection.

SO GL — System Operation Guideline (Regulation 2017/1485) Commission Regulation establishing rules for electricity transmission system operation: operational security, load-frequency control, reserve dimensioning (FCR, FRR, RR), prequalification, TSO-DSO data exchange, and cooperation on reserve delivery from distribution systems. Foundational regulation that the Network Code on Demand Response builds upon. See Source - SO GL (Regulation 2017-1485).

Sistahandsleverantör (Swedish: supplier of last resort) The supplier obligated to serve electricity customers who lack an active supply contract — replacing the abolished anvisade elavtal under the new Elmarknadslag (Prop. 2025/26:240; in force 1 July 2027). The leveransskyldig sistahandsleverantör is the supplier with the largest market share in a given local-grid area; the customer may choose freely among the contracts that supplier offers. Implements the EU requirement (revised Directive 2019/944) that member states ensure continuity of supply via a transparently designated supplier of last resort, at least for household customers. (Source - Prop. 2025-26-240 Nya lagar om elsystemet (2026))

Ställningstagande (Swedish) A formal regulatory guidance document published by Ei (and potentially other Swedish authorities) clarifying how specific rules should be interpreted and applied. Introduced by Ei in 2025 as a new publication series in response to stakeholder requests for clearer guidance. Can be updated when legal practice or regulation changes. Ei2025:01 (on villkorade avtal) was the first in the series. Narrower in scope than a full report (R-series); more binding in intent than an FAQ — summarizes Ei’s official interpretive position. (Source - Ei Ställningstagande Ei2025-01 Villkorade avtal (2025))

Stamnät (Swedish) The Swedish transmission network, operated by Svenska kraftnät at 220–400 kV.

Strategisk reserv (Swedish: strategic reserve) Sweden’s strategic electricity reserve mechanism, introduced by Lag 2025:50 as a replacement for the previous effektreserv (terminated March 2025). Purpose: provide backup capacity for periods of extreme demand or generation shortfall, reducing LOLE (Loss of Load Expectation) to a 1.0h target. Technology-neutral (production and load-shedding eligible); minimum 1 MW and 2h endurance; annual and multi-year contracts (multi-year must be fossil-free); BSP/BRP cannot overlap to avoid crowding out mFRR bids. The first procurement failed — all 713 MW of bids exceeded the CONE price cap of 120,000 SEK/MW — after which a redesigned model tying payment to LOLE reduction contracted 350 MW on 8 January 2026, improving LOLE from 1.6h to 1.2h; BRPs in SE3/SE4 pay a cost levy (Lag 2025:50, Förordning 2025:835), and Ei’s review of CONE and VoLL is expected autumn 2026. See Strategisk Reserv. (Source - Elmarknadsrådet Meeting 1 February 2026, Source - Svk Kraftbalansen Höst 2025)

sthlmflex Stockholm flexibility market — a Swedish TSO-DSO flexibility market R&D project (FoU-projekt) operated by Svenska kraftnät with Vattenfall Eldistribution and Ellevio as buying DSOs (and E.ON Energidistribution from season 3). Ran for four seasons: V2020/21–V2023/24. Used NODES as the market platform and the SWITCH flex tool as the DSO operator interface. Key feature: cross-DSO abonnemangsväxling enabled region-wide resource pooling. Closed after S4 (no separate season 4 report published as of April 2026). See Flexibility Market.

Styrbar effekt (Swedish) Controllable power — the portion of a customer’s connection capacity that the DSO can curtail under a villkorat avtal. Must be curtailed within 15 minutes of signal.

Subscription level (Swedish: abonnemang mot överliggande nät) The annually contracted maximum power that a regional DSO may draw from the TSO grid (or a local DSO from a regional DSO) without prior notice. Central to the Swedish congestion management business case: when Svenska kraftnät denies a subscription raise pending grid reinforcement, the DSO must manage demand below the limit — creating the demand for a local Flexibility Market. The TSO can also grant temporary subscriptions (up to 7 days, retractable at any time) for short-term needs at ~240–280 SEK/MWh, which acts as a price ceiling on DSO willingness to pay for flexibility. (Source - CoordiNet D4.7.2 Swedish Demonstration (2022))

SWITCH Digital platform built by E.ON Energidistribution for distribution-level flexibility market operation and Villkorade Avtal integration. Developed in-house during the CoordiNet demonstration (2019–2022); continues as E.ON’s live flexibility market platform post-project. Architecture: (1) market tool — bid management, PTDF-weighted merit order, mFRR forwarding; (2) flex tool — DSO operator interface, ML load forecast, subscription limit monitoring, integration with TSO SUSIE subscription system; (3) FSP interface — sell order API, baselines, delivery history; (4) P2P platform — capacity trading during maintenance. The flex tool component was also adopted by sthlmflex (Stockholm), which uses NODES as the market tool. See SWITCH.

Systemansvarig (Swedish) — system-responsible (grid) company The term that replaces nätföretag in the new Elmarknadslag (2026:1281), emphasising that a company conducting nätverksamhet also carries a system responsibility, not merely ownership of lines. Exception: companies holding only a linjekoncession with a single connected customer within the same group. Distinct from the older systemansvarig myndighet (the TSO system-responsibility role held by Svenska kraftnät). Distribution companies are systemansvariga för distributionssystem; transmission companies such as Svenska kraftnät, and also Baltic Cable AB, are systemansvariga för överföringssystem (transmission → överföring; överföring av el → transport av el). (Source - Elmarknadslag (2026-1281), Source - Ei Nya Ellagar och Ny Förordning (2026))

System states (SO GL term) Five states defined by SO GL Art. 18: Normal (all limits met, sufficient reserves for N-1) → Alert (limits met but reserves insufficient or N-1 violation possible) → Emergency (security limits violated) → Blackout (>50% demand lost) → Restoration (recovery underway). Reserve availability is a key criterion — when reserves are exhausted, TSOs may require demand units to change consumption.

T

Transmissionsnätsavgiften (Swedish) — transmission network charge What producers and grid companies with a subscription point on Svenska kraftnät’s 400 and 220 kV network pay to use it; called transmissionsnätstariffen until 2026. Two components until 2026 (power fee, energy fee); four from 2027 (fixed fee, energy fee, customer-specific fee, power fee). See Transmission Network Charge. (Source - Svk Transmissionsnätsavgift 2027 (2026))

Table of Equivalences (NC DR term) Mechanism enabling value stacking: if a resource is prequalified for one flexibility product, it may be automatically recognized for other products with equivalent technical requirements. Published by TSOs/DSOs. Transforms the business case by enabling multiple revenue streams from a single qualification. See Network Code on Demand Response.

TDTR — Time-Driven Transport Right (Netherlands) A standardized conditional/flexible connection agreement offered by the Dutch TSO TenneT: contracted power is guaranteed 85% of the year in exchange for a 50% network-fee discount, with the customer accepting limitation (the source says “a few hours”, though an 85%-of-year guarantee leaves up to ~15% of the year). By analysing actual annual utilisation, TenneT identified ~9 GW allocatable to new customers this way — the headline contractual capacity-release example. Firm 100%-access capacity is increasingly treated as a premium “luxury good.” A concrete model for standardized, predictable flexible-connection terms. (Source - Energiforsk 2026-1190 Kapacitet för Tillväxt (2026))

TMV — Tilknytning med vilkår (Norwegian) Norway’s direct structural equivalent of Swedish villkorade avtal: a voluntary connection agreement where the customer accepts reduced delivery reliability (curtailment or capacity reduction in certain situations) in exchange for faster grid access, typically where reinforcement would otherwise take too long. Studied specifically for EV-charging-operator connections by SINTEF’s MegaCharge project, which found lack of cross-DSO standardization the main scaling barrier and explicitly looked to Sweden’s Energiföretagen/OpenADR standardization work as a model. (Source - SINTEF PN26-00117 Tilknytning Ladestasjoner Med Vilkar (2026))

Temporary limits (NC DR term) Short-term constraints set by connecting or impacted system operators on specific grid elements, SPUs, SPGs, or parts of SPGs in operational planning to ensure that flexibility delivery does not compromise grid safety. Applied close to real-time — distinct from the longer-term grid prequalification. Must be communicated at least 1 hour before balancing energy gate closure. System operators must minimise the number, size, frequency, and duration of temporary limits to reduce market impact. Methodology must be public, transparent, verifiable, and accurate. (Art. 50, Source - NC DR Amended Text (ACER Recommendation 01-2025 Annex 1)) The draft Swedish SO GL Art. 182 agreement uses tillfälliga gränser in a similar sense, with its own rules: at most 2 days, non-discriminatory, notified to the BSP and Svk by 14:00 on D-2. (Source - Svk Energiföretagen SO GL Art 182 Avtal (2026))

TEN-E — Trans-European Networks for Energy EU regulatory framework governing cross-border energy infrastructure planning, permitting, and financing. Established by Regulation (EU) 2022/869 (currently in force; to be replaced by COM/2025/1006). Provides for: (1) the Union list of PCIs (Projects of Common Interest) and PMIs (Projects of Mutual Interest); (2) streamlined permitting for listed projects; (3) CEF (Connecting Europe Facility) co-funding eligibility; (4) the TYNDP (Ten-Year Network Development Plan) process by ENTSO-E as the infrastructure planning mechanism. The 2025 revision (COM/2025/1006) strengthens EU-level scenario development by transferring central scenario development from ENTSO-E to the Commission, introduces Energy Highways, broadens PCI scope to non-wire solutions and internal reinforcements, and reforms cross-border cost allocation. (Source - European Grids Package COM2025-1005)

Tillgänglighetsordrar (TO) “Availability orders” — the medium-horizon product in SWITCH, complementing Säsongstillgänglighet. DSO places orders up to 7 days ahead based on current forecasts; clearing D-2 10:30; activation D-1 only (no intraday). FSPs bid an activation price; lowest price wins. Both availability and activation fees apply. Suited to FSPs that cannot guarantee long-term availability but can commit days ahead. See SWITCH › Products. (Source - SWITCH User Documentation (2026))

Timeffektavgift (Swedish) — hourly demand charge A capacity (effekt) charge applied at hourly granularity rather than as a monthly peak — the price per kW varies by hour to reflect when the grid is constrained. In its most developed form (Energiforsk UniFlex, Source - Energiforsk 2026-1193 Unison Prissignal Timeffektavgift (2026)) it is dynamic and locational — set continuously from the grid’s actual load and optionally differentiated by station — and aims to be a “unison” signal reflecting both grid and electricity-market value. Contrast with the static, annually-fixed effektavgift. A candidate design for Sweden’s new effektavgift model (due April 2027). See The Signal Stack — Price Signal Collisions at the Customer DER, Swedish DSO Tariff Reform — Three Parallel Tracks (2025–2027).

Timmedeleffekt (Swedish) Hourly average power (kW) — the average power drawn or injected during a one-hour interval, equal to the energy (kWh) transferred in that hour. The standard measurement unit in Swedish effektavgift billing calculations; one or more timmedeleffekter per billing period are selected and averaged to determine the debiteringsgrundande effekt. Measured at the connection point using smart meter interval data. Distinct from contracted effect (the agreed subscription level) and from toppeffekt (instantaneous peak — not used in Swedish DSO billing). (Source - Ei PM2026-07 Effektavgift Supervision)

Timprisavtal (Swedish) Hourly electricity pricing contract — a retail supply contract where the customer pays the actual spot market price for each hour of consumption, plus a fixed markup and network tariff. Also called rörligt timpris. Key metric for consumer demand flexibility readiness: as of 2024, only ~12–13% of Swedish households effectively benefit from hourly pricing, despite ~15% holding formal timprisavtal — the gap reflects customers in multi-metered buildings who lack an individual grid connection (Ei Flexläget 2026, Ramboll 2024). Timprisavtal creates an implicit Demand Response incentive by exposing customers to spot price variation. Contrast with månadsrörligt (monthly average price, no hourly signal). Note: ~9% of consumers confuse the two (IVL 2023). See Demand Response. (Source - Ei Flexläget 2026 (PM2026-02), Source - Ramboll Nyckeltal Hushålls Efterfrågeflexibilitet (2024))

Toleransband (Swedish) — tolerance band The former mechanism in the Nordic mFRR budväljare that allowed a margin around the activated need. Its optimisation complexity lengthened the bid selector’s computation time so the algorithm could not always reach an optimal solution within its time limit — the root cause of illogical bid selections and extreme imbalance prices. Replaced by elastisk efterfrågan in the Nordic selector from 22 June 2026 (Svk’s local selector still uses it). See Balancing Markets. (Source - Svk Elastisk Efterfrågan mFRR (2026))

Tolling agreement A commercial structure in which a battery developer grants a counterparty (the “toller”) exclusive access to the battery’s capacity for a fixed term, in exchange for a guaranteed payment. The toller bears all merchant risk — deciding when and in which markets to dispatch the asset — while the developer receives predictable revenue independent of market outcomes. Emerging as a dominant BESS financing structure in Europe (approximately 20 signed by mid-2026) as banks have become reluctant to lend against merchant battery risk. Tolling agreements isolate the storage merchant layer in a separate bilateral structure, distinct from a hybrid PPA (which bundles renewables + storage in one contract but exposes the offtaker to battery optimisation complexity most corporate buyers cannot evaluate). (Source - Powernaut Flex Trends Report (2026), Source - Konsultrapport Balansansvarigas förutsättningar Merlin Metis (2026))

TOTEX — Total Expenditure Combined benchmarking framework covering both capital expenditure (CAPEX) and operating expenditure (OPEX) in a single cost efficiency incentive. The key reform in Ei’s RP5 (2028–2031) revenue regulation methodology for Swedish DSOs. Achieves lösningsneutralitet — eliminates the CAPEX bias that systematically favored grid investment over flexibility procurement. Enstegsmetoden confirmed as the chosen method (December 2025); full cost coverage at Q3; no general efficiency requirement; 8-year realiseringstid. Not only a Swedish policy choice: the Commission reads the 2024 amendment to Art. 18 of the Electricity Regulation as already requiring tariffs to consider both capital and operational expenditure, with incentives including anticipatory investment. See Enstegsmetoden, Effektiviseringsincitament. (Source - Ei Inriktning intäktsramar 2028-2031 (2025), Source - Ei Effektiviseringsincitament Webb (2026-05-12), Source - C(2026)126 Future Proof Network Charges Guidelines)

Transfer of Energy Service Provider (NC DR term) Entity handling energy reallocation between Balance Responsible Party portfolios when flexibility activation shifts energy between market participants.

TSO — Transmission system operator Entity operating the high-voltage transmission grid. Responsible for system balance, cross-border flows, and grid development. In Sweden: Svenska kraftnät. See Transmission System Operator.

Two-way contract for difference (two-way CfD) EU legal definition (Regulation 2024/1747, Art. 2(76)): “A contract between a power-generating facility operator and a counterpart, usually a public entity, that provides both minimum remuneration protection and a limit to excess remuneration.” The EU’s mandatory instrument for public support for new low-carbon generation from 17 July 2027 (Art. 19d, Regulation 2024/1747). Applies to: wind, solar, geothermal, run-of-river hydro, and nuclear. Structure: a floor (strike price — minimum remuneration) protects against low prices; a ceiling — above the strike price, revenues are redistributed to final customers (preventing windfall profits). Participation is voluntary; early termination requires penalty clauses. Offshore hybrid projects: deadline 17 July 2029. Distinguished from virtual PPAs (which use a similar CfD financial structure but are market-based private contracts, not public support instruments). (Regulation 2019/943, Art. 2(76) and Art. 19d, as inserted by Regulation 2024/1747; Source - Electricity Market Design Reform Regulation (EU 2024-1747))

U

Unbundling Structural separation of network operation (natural monopolies) from competitive activities (generation, retail). Required by EU law to prevent market distortion. See Natural Monopoly.

UniFlex (Energiforsk project) The Energiforsk project Unison prissignal för ökad flexibilitet, which develops the timeffektavgift — a dynamic, locational hourly capacity tariff reflecting both grid and electricity-market value, intended to give DER a single coherent (“unison”) price signal instead of colliding ones. Case study on the Sala-Heby grid; surfaces the granularity-vs-fairness tension (nätstation-level pricing gives sharp, dispersed spikes; one grid-wide price reads as unfair to customers with no local shortage). See The Signal Stack — Price Signal Collisions at the Customer DER, Swedish DSO Tariff Reform — Three Parallel Tracks (2025–2027). (Source - Energiforsk 2026-1193 Unison Prissignal Timeffektavgift (2026))

Uthållighet / Återhämtning (Swedish) “Endurance / Recovery” — two paired parameters in SWITCH market products. Uthållighet is the maximum number of consecutive hours a resource can deliver flexibility (e.g., a battery can sustain 1 hour). Återhämtning is the minimum rest time required before the resource can deliver again. When a DSO specifies uthållighet requirements, resources with shorter endurance receive a proportionally reduced availability fee via the Df factor: Df = 0.5 + (resource endurance / requested endurance) × 0.5. A resource with half the required endurance receives Df = 0.75 (75% of the maximum availability fee). Resources can still be available for all hours in the window even if they cannot sustain the full period at once. (Source - SWITCH User Documentation (2026))

V

V2B — Vehicle-to-Building Bidirectional power transfer from an EV battery to a commercial or industrial building energy management system. A subset of V2X. Used for demand charge reduction and building energy optimization. See V2X.

V2G — Vehicle-to-Grid Bidirectional power transfer from an EV battery back into the electricity grid, turning the vehicle into a distributed energy resource. Requires a bidirectional charger (EVSE), an inmatningsabonnemang, and compliance with ISO 15118-20 / OCPP 2.1. Grid services V2G can provide include FCR, aFRR/mFRR, local DSO flexibility, and energy arbitrage. The Swedish regulatory framework for V2G contains several unresolved grey areas: classification ambiguity (microproduction vs mobile injection point), dubbelbeskattning, physical address registration requirements, and nätkoder not adapted for mobile resources. Swedish fleet potential: ~5,000 MW by 2030 under optimistic assumptions. See Vehicle-to-Grid. (Source - Power Circle V2X Synthesis 2024, Source - KTH Thesis V2G Sweden 2024)

V2H — Vehicle-to-Home Bidirectional power transfer from an EV battery to the owner’s own household — enabling self-supply, backup power during outages, and optimization against time-of-use tariffs. A subset of V2X. V2H is generally viewed as a gateway product for V2G adoption: consumers experience direct, immediate financial benefit before engaging with the more complex grid services market. (Source - KTH Thesis V2G Sweden 2024)

V2L — Vehicle-to-Load Direct AC power output from an EV to portable equipment or loads — without connecting to any grid. Used for construction sites, camping, or emergency power. A subset of V2X. No grid injection subscription or bidirectional charger required (the vehicle’s inverter provides the output directly). See V2X.

V2X — Vehicle-to-Everything The umbrella term for all bidirectional power transfer from an EV battery to any external system. Sub-categories: V2G (grid), V2H (household), V2B (building), V2L (portable loads), V2V (vehicle-to-vehicle). Requires a bidirectional charger for grid-connected variants (V2G, V2H, V2B) — either AC (cheaper wallbox, inversion inside vehicle OBC) or DC (more expensive wallbox, better protocol maturity). See Vehicle-to-Grid. (Source - Power Circle V2X Synthesis 2024)

Value stacking A single flexibility resource earning revenue from multiple markets and products simultaneously. Enabled by the NC DR’s Table of Equivalences. Key for making distributed flexibility economically viable.

Värdefaktor (Swedish) — capture rate A generator’s capture price (intjäningsförmåga — its own production-weighted average price, i.e. what it actually earns per MWh sold) expressed as a percentage of the market’s arithmetic average price. A capture rate under 100% means the technology earns less than the average MWh in that market — a structural feature of weather-dependent generation, which tends to produce more exactly when its own output (and other similar generation) is depressing the price (the cannibalization effect). Empirically for SE4: wind ~74–84%, solar ~54–60%, both declining as more of the respective technology is added. A capture price must exceed production cost for new capacity to be economic — though a real 2026 Danish offshore wind CfD auction cleared well above both cost estimates and modelled capture prices, showing the comparison alone doesn’t determine what secures investment. See Merit-Order Price Suppression from Weather-Dependent Generation. (Source - Energiforsk Elprispåverkan Vindkraft Skåne SE4 (2026))

VeckoFlex (Swedish) “Week flex” — a medium-term availability product used in sthlmflex season 2 (V2021/22), providing weekly availability reservation for flexibility resources. Replaced in season 3 (V2022/23) by ShortFlex Availability, which improved targeting by allowing DSOs to announce specific forecast-driven hours rather than a fixed weekly schedule. Data for VeckoFlex in season 1 appears as “ShortFlex Availability” in the cross-season tables with 144 MWh procured. (Source - sthlmflex säsong 3 (2022-2023))

Villkorade avtal (Swedish) / Flexible connection agreement (NC DR term) See flexible connection agreement (FCA). The Swedish DSO mechanism; the NC DR recognizes these as flexible connection agreements and requires coordination with market-based procurement. See Villkorade Avtal.

Virtual power plant (VPP) Cloud-based system aggregating distributed energy resources to operate as a single dispatchable unit. The NC DR does not use this term — the regulatory equivalent is a Service Providing Group (SPG). See Virtual Power Plant.

W–Z

Wholesale markets System-wide markets for electricity trading. In the Nordics, operated by Nord Pool (day-ahead) and via continuous intraday trading. Distinguished from Balancing Markets (real-time) and Flexibility Markets (local/DSO).

Sources

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