SolarIndustry.ro Weekly Briefing · Week ended 26 Aug 2026
Solar set the record.
The scarce product was still time.
Romania's utility-scale photovoltaic fleet set another instantaneous production record while 2026 grid connections passed 2.5 GW. Yet the market did not reward every solar hour equally: weekday scarcity kept daylight electricity expensive, the weekend pushed the solar-window price proxy back toward zero, and several days moved from material midday exports to heavy evening imports within hours. The evidence points to a market entering its next constraint: not simply how many renewable megawatts can be built, but when they can be delivered, how much connection capacity they require at peak output, and whether storage can move energy into the hours in which the system actually needs it.
01 / Executive position
More megawatts did not remove the timing problem.
The previous issue showed solar-hour value recovering under scarcity. This week tests whether that recovery was structural. It was not: the result depended heavily on day type and system tightness.
Romania reached 3,453 MW of instantaneous dispatchable PV on 20 August, while the seven-day PZU base averaged 821.56 RON/MWh. But the 08:00–17:00 price proxy split sharply: 717.36 RON/MWh on weekdays versus only 145.98 RON/MWh across 22–23 August. The weekly solar-window/base ratio slipped to 67.4% from 69.1% in the prior review period. Selected 22–26 August operating days then moved from midday net export to evening import by 2.25–3.76 GW. ANRE's 24 August draft explicitly recognizes the system logic: co-located storage can defer renewable evacuation and limit peak grid export. The decision implication is therefore operational: underwrite solar and BESS against time profile, connection envelope and service stack—not installed MW or a simple day-ahead spread alone. [S01] [S02] [S08]
02 / Market snapshot
Scarcity held the weekly average up. Profile risk widened underneath it.
PZU figures below use official delivery-day PT15 outcomes. “Solar window” is SolarIndustry.ro's unweighted 08:00–17:00 local-time price proxy. It is deliberately not described as a capture price.
Source: OPCOM PZU PT15 official results, retained and normalised by SolarIndustry.ro. The daylight series is an unweighted 08:00–17:00 price proxy. It is not generation-weighted and therefore is not a solar capture-price calculation. [S02]
03 / System reference layer
Connections accelerated. “Connected” still does not mean one uniform commercial state.
Transelectrica's 20 August disclosure is the week's strongest capacity datum because it reports actual connection to transmission or distribution networks. It also contains an important qualification: assets range from commercially licensed plants to installations still undergoing functional and conformity testing.
Transelectrica reports a 2,514 MW total. Its rounded technology components sum to 2,515 MW; this report preserves the source values rather than silently reconciling the one-megawatt difference. [S04]
Average consumption across the 168 retained local-hour records supplied for 20–26 Aug. This is preferable to averaging raw daily snapshots because each local hour carries equal weight in the selected seven-day register. [S01]
Average reported solar across the same 168-hour register. The public operational solar line does not represent all behind-the-meter prosumer production. [S01]
Dispatchable PV measured at 13:04 on 20 Aug. SolarIndustry's retained daily maximum was 3,451 MW; the two-megawatt gap is consistent with different sampling timestamps. [S05]
Reported for 1 Aug alongside 989 MW by Economica based on Transelectrica data. The 20 Aug primary Transelectrica release confirms the 989 MW power figure but does not restate MWh. [S21]
Physical network connection or operating evidence. Still distinguish commercially licensed operation from testing.
Highest near-term system relevancePhysical works underway. Does not establish energisation date, export rights or achieved commissioning.
Execution evidenceRegulatory milestone toward implementation. Not equivalent to construction completion or grid injection.
Permitting evidenceTechnical connection terms exist, but reinforcement, construction permits and future network capacity can remain critical.
Connection pathwayCompany intention or development portfolio. It is excluded from installed-capacity totals until stronger evidence appears.
Lowest physical certainty04 / Week in review
The material developments, with maturity attached.
The timeline favours developments that changed operational evidence, regulation, project maturity or grid deliverability. Re-publication of older approvals is not treated as a new market event.
Dispatchable PV reached 3,453 MW at 13:04.
The instantaneous Transelectrica reading set a new utility-scale PV record. Economica reported national grid consumption near 4.8 GW at that moment and material exports. The prosumer-production estimate cited in the article cannot be added mechanically to the utility reading because the split between self-consumption, local storage and network injection is unknown. [S05]
Transelectrica passed 2.5 GW of 2026 production-and-storage connections.
The operator reported 2,514 MW: 1,331 MW PV, 663 MW storage, 496 MW wind, 20 MW hydrocarbons and 5 MW biogas. The milestone was crossed with the 76.76 MW / 150.288 MWh Părău storage installation. Crucially, Transelectrica says these assets span stages from commercial licences to internal functional and conformity testing. [S04]
ANRE opened a transition consultation for prosumer quantitative compensation.
The draft follows Law 160/2026 and addresses existing contracts after the 26 July legal change. ANRE's supporting material moves post-26-July delivery toward monthly settlement rather than creation of new 24-month kWh carry-forward rights, while preserving historical rights separately. Comments are due through 31 August; this was not a final order at the research cut-off. [S09]
Scatec financed and started construction on 77 MW Urleasca wind.
The wind project is outside the solar core but relevant to Romania's multi-technology buildout. Approximately 57% of expected production is covered by a CfD; Scatec also reports 190 MW of Dobrun & Sadova solar already under construction. The event therefore adds execution and financing evidence, not new operating solar capacity this week. [S11]
Rompetrol paired 4.8 MW PV with approximately 9 MWh storage at Vega.
The refinery project carries an estimated investment of nearly 27 million lei, including approximately 7 million lei from the Modernisation Fund, with implementation by 31 December 2028. Rompetrol forecasts more than 6,200 MWh/year from the PV plant, all for self-consumption, equivalent to roughly two-thirds of Vega's budgeted 2025 electricity use. The battery's MW rating is not disclosed, so duration cannot be inferred. [S10]
Both Cernavodă reactors were still in safe shutdown.
Nuclearelectrica reported both units in a safe shutdown state and said restart timing would depend on forecasts. SolarIndustry's retained operational feed continued to show zero nuclear output through 26 August. That matters directly to price interpretation: high weekday solar-hour prices occurred while a large block of firm nuclear generation was absent. [S06] [S01]
ANRE proposed removing the 30 EUR/kW establishment guarantee from added co-located storage.
The consultation proposes that storage added to a production facility at the same production/consumption site be excluded from the financial guarantee, leaving the guarantee calculated on the relevant new generating capacity. ANRE explicitly justifies the change by storage's ability to hold generation locally, shift evacuation timing, reduce peak export and use available network capacity more efficiently. The proposal remains draft. [S07] [S08]
WALDEVAR disclosed 95 MWp solar + 220 MWh BESS construction scope for SANY in Dolj.
The two co-located Dobrești projects include a 110/20 kV substation and 110 kV underground line. The company estimates roughly 135 GWh/year of PV generation. The symbolic site event occurred on 14 August and the detailed announcement followed on 25 August, so this briefing classifies it as a construction disclosure during the week—not a 25 August commissioning. Battery power in MW was not disclosed, preventing a defensible duration calculation. [S12]
MVM advanced the 24.6 MW Arcuș solar project into the establishment-authorisation stage.
The company release carried by Bursa states 24.6 MW maximum installed grid capacity and 21.21 MW maximum export capacity. The distinction is commercially important: installed generation and permitted evacuation are not automatically identical. The authorisation is an implementation milestone, not evidence of generation or commissioning. [S14]
Eurowind disclosed ATRs for 2,307.4 MW—but the approvals date from June.
Seven projects were announced, dominated by wind. Solar relevance sits at Mănești, Prahova, with 49 MW PV plus BESS. Eurowind states the ATRs were obtained in June and the projects are expected to connect after 2030, with delivery dependent on network reinforcement and timely construction permits. This is a strong example of why an ATR should not be added to near-term operating supply. [S15]
Casa Verde Baterii consultation added a beneficiary ambition, not a final programme launch.
At the 26 August discussion, a Ministry of Environment state secretary said the mathematical minimum would be roughly 27,000 beneficiaries at maximum grant, while the ministry's ambition is approximately 35,000–40,000. The applications still depend on AFM launching the final session. Core draft parameters were covered in the prior briefing and are not repeated here as a new policy event. [S16]
05 / Market and system analysis
The market moved from one scarcity story into two operating regimes.
The strongest analytical conclusion this week is not that solar prices “fell” or “recovered”. Both happened. The relevant distinction is whether the system was scarcity-dominated or abundance-dominated during solar hours.
05.1 / Solar value
Weekday scarcity protected absolute daylight value. The weekend exposed the underlying cannibalisation risk.
The 20–26 August PZU base averaged 821.56 RON/MWh, 3.2% above the 796.32 RON/MWh average for 13–19 August. The 08:00–17:00 proxy averaged 554.11 RON/MWh, only 0.7% above the prior 550.36 RON/MWh. Because the full-day base strengthened faster than daylight pricing, the proxy/base ratio moved from 69.1% to 67.4%. The absolute solar-window price therefore held up while relative profile value deteriorated. [S01] [S02]
That weekly average conceals a much stronger split. Across the five weekdays in the review window, the base averaged 905.75 RON/MWh and the solar window 717.36 RON/MWh, a 79.2% ratio. Across Saturday and Sunday, the base averaged 611.10 RON/MWh while the solar window collapsed to 145.98 RON/MWh, only 23.9% of base. Put differently, the unweighted daylight discount widened from 20.8% on weekdays to 76.1% on the weekend.
Sunday 23 August is the cleanest stress point. Its base was 569.22 RON/MWh, but the solar window averaged only 76.98 RON/MWh, an 86.5% discount. The lowest PT15 price was 0.02 RON/MWh. Saturday reached an exact reported low of 0.00 RON/MWh. There were still no negative PT15 results across the seven-day review. This matters: merchant solar can suffer severe profile compression well before negative-price counts become a useful alarm.
The retained public operational solar series is hourly and represents a specific reported generation scope; OPCOM settlement prices are PT15 and market-wide. The report does not assume those scopes and settlement intervals are interchangeable. The 08:00–17:00 series is therefore labelled only as a price proxy.
05.2 / Grid deliverability
The daily problem is increasingly a movement from exportable noon energy to import-dependent evening power.
The hourly operational register shows repeated intra-day reversals. The exhibit below takes the most negative retained exchange observation between 10:00 and 16:00 and compares it with the largest import reading between 18:00 and 22:00 for 22–26 August. Positive exchange means net import; negative means net export. The calculation uses hourly arithmetic means from the retained public snapshots, not energy-settlement MWh. [S01]
MW · selected 22–26 Aug · storage series = largest reported storage output in the 18:00–22:00 window.
The largest observed reversal in this sample occurred on 23 August: from –1,690 MW at 11:00 to +2,071 MW at 19:00, a 3,761 MW swing. Reported storage output reached 535 MW at 21:00 that evening. On 25 August, the system moved from –1,563 MW at noon to +1,486 MW at 19:00, a 3,049 MW reversal. On 26 August, it moved from –683 MW at noon to +1,899 MW at 19:00, while reported storage output later reached 592 MW at 20:00.
This is why the 24 August ANRE draft is analytically important beyond its financing mechanics. ANRE states that hybrid storage can keep electricity local rather than exporting it at the instant of production, manage the evacuation moment, limit peak exported power and use available network capacity more efficiently. That is a regulatory acknowledgement of storage's connection-envelope value, distinct from arbitrage. [S08]
05.3 / Storage value
A price spread is an input to battery economics. It is not a battery margin.
Romania now has enough storage activity for the public system feed to show a visible evening contribution. Across the five selected 22–26 August days, the largest retained evening storage readings ranged from 484 MW to 592 MW, averaging 524 MW across those daily peaks. This is operationally meaningful, but the feed does not disclose asset-level state of charge, charging energy, losses, degradation, reserve obligations or trading positions.
Accordingly, the difference between a cheap solar hour and an expensive evening hour cannot be represented as realised BESS profit. A defensible revenue model would need charging price and quantity, discharge price and quantity, round-trip efficiency, degradation cost, availability, auxiliary load, imbalance cost, ancillary-service commitments, balancing-market revenues, grid charges and any curtailed or otherwise stranded renewable energy that the battery captures.
Energy shifting
Daylight-to-evening price separation is an opportunity signal, not a realised margin. Dispatch duration and cycling strategy determine how much can actually be captured.
Balancing & reserves
BESS can provide fast flexibility, but no public asset-level revenue stack was identified for the reviewed projects. Do not add theoretical services as if simultaneously monetised.
Grid-envelope value
Co-located batteries can reduce peak export and shift evacuation timing. ANRE now explicitly cites this rationale in its draft guarantee change.
Self-consumption
Industrial users can value avoided imports and resilience differently from merchant BESS. Rompetrol's Vega project is a current C&I example, but its battery MW is undisclosed.
Capital support
Grant support changes invested capital and competitive bidding strategy. It does not create operating revenue and should not be confused with market value.
Părău provides another reminder about dimensional discipline. Transelectrica reports 76.76 MW / 150.288 MWh, which gives a nominal energy-to-power ratio of 1.96 hours. That simple quotient is not usable duration: state-of-charge limits, warranted depth of discharge and auxiliary consumption are not disclosed. Likewise, WALDEVAR/SANY discloses 220 MWh at Dobrești without the BESS MW rating, and Rompetrol discloses approximately 9 MWh at Vega without power. Neither project should be assigned a duration by assumption.
05.4 / Connection economics
ANRE's draft can remove material collateral friction for hybrid storage—but it is not a cash grant.
The current establishment-authorisation guarantee is 30 EUR/kW of installed capacity according to the ATR. ANRE's 24 August proposal would exempt storage added to an existing or new production site from that guarantee and calculate the relevant guarantee on generation rather than the added storage installation. Comments remain open for 30 days from publication. [S07] [S08]
The change could therefore improve development capital efficiency for hybrid projects, especially portfolios carrying multiple large battery additions. But it does not solve network capacity, construction-permit timing, connection works, operating licence, revenue-stack bankability or the technical performance requirements of the BESS.
Eurowind's 26 August disclosure is the counterweight. Its 2,307.4 MW of ATRs sound large, but the approvals were obtained in June, the portfolio is mostly wind, and the company itself says connection is expected after 2030 and depends on network reinforcement and construction permits. Mănești's 49 MW PV+BESS component is relevant, but an ATR is a path to connection—not delivered power. [S15]
05.5 / Prosumers & C&I
Physical storage becomes more relevant when the commercial model stops behaving like a long kWh bank.
ANRE's 20 August transition proposal responds to the July legal change in prosumer quantitative compensation. The regulator's supporting logic moves newly delivered energy toward monthly validated measurement and settlement rather than creation of new quantitative carry-forward extending for up to 24 months, while preserving rights accumulated under the previous regime. Because the consultation was still open at the cut-off, this briefing treats those mechanics as proposed transition rules rather than a final supplier process. [S09]
The commercial implication is directional, not universal. If surplus electricity can no longer be treated as a newly accumulated long-dated kWh balance in the same way, the relative value of increasing physical self-consumption can rise. But the optimal battery size depends on retail import tariffs, export remuneration, load profile, available subsidy, inverter limits, battery capex, round-trip losses and cycle life. A programme paying for 12 kWh batteries does not mean 12 kWh is technically or economically optimal for every prosumer.
Rompetrol's Vega design shows the same logic at industrial scale: the disclosed PV production is intended entirely for self-consumption, with storage added inside the refinery project. This is different from a merchant standalone battery and should be underwritten against avoided procurement cost, process load and resilience requirements, not solely PZU arbitrage. [S10]
06 / Project and industry ledger
Pipeline is abundant. Evidence quality and execution stage are the differentiators.
The ledger below keeps project power, energy capacity, grid scope and maturity separate. It deliberately does not aggregate announced pipelines into national installed capacity.
| Project / company | Disclosed scope | Maturity at cut-off | Analytical read-through |
|---|---|---|---|
| Părău BESSNational connection milestone | 76.76 MW / 150.288 MWh | ConnectedTranselectrica milestone; broader connected cohort includes mixed test/commercial stages. | Confirms physical storage build-out. Nominal E/P ratio 1.96 h; usable duration not disclosed. [S04] |
| Vega Ploiești / Rompetrol | 4.8 MW PV + ~9 MWh BESS; ~27m lei investment | DevelopmentTarget implementation by 31 Dec 2028. | Behind-the-meter hybrid case. BESS MW undisclosed, so no duration or power-value inference. [S10] |
| Dobrești / WALDEVAR + SANY | 95 MWp PV + 220 MWh BESS + 110/20 kV substation + 110 kV line | Construction disclosureSymbolic inauguration 14 Aug; detailed release 25 Aug. | Grid infrastructure is inside the EPC narrative, which is positive for deliverability, but energisation is not yet evidenced. BESS MW undisclosed. [S12] |
| Curtici BESS / ELCO | 55 MW BESS; €1.6m ex-VAT related works contracts | EPC works contractClient undisclosed. | The €1.6m figure covers external civil/electrical works described by ELCO, not the complete battery system. It must not be used as €/MW total BESS capex. [S13] |
| Arcuș / MVM Energie România | 24.6 MW installed; 21.21 MW stated maximum export | Establishment authorisation | Useful real-world example that nameplate and permitted grid evacuation can differ. No operating generation yet. [S14] |
| Mănești / Eurowind | 49 MW PV + BESS; battery size not disclosed | ATR obtained JuneAnnouncement 26 Aug; connection expected after 2030. | Important grid-rights milestone but low near-term physical supply relevance. Reinforcement and permits remain dependencies. [S15] |
| Gura Ialomiței / Aukera | 150 MW / 300 MWh first phase; expansion described to 250 MW / 500 MWh | Company-reported operating + financed expansion | Aukera also describes a medium-term Romanian programme exceeding 1 GW and another 700 MW standalone construction pipeline. Treat forward figures as company pipeline, not installed stock. [S17] |
| Dobrun & Sadova / Scatec | 190 MW solar | Under construction | Not a new 20–26 Aug solar commissioning; cited by Scatec as the solar leg of its Romanian multi-technology platform. [S11] |
Aukera's >1 GW ambition is material—but still a company pipeline.
The 26 Aug industry interview describes 150 MW / 300 MWh already commissioned at the first Gura Ialomiței phase, financing for expansion to 250 MW / 500 MWh and plans to start another 700 MW of standalone projects. The evidence supports strong developer intent and execution momentum; it does not support adding the full programme to national operating capacity. [S17]
RPIA expects >5 GW of new PV by end-2028.
RPIA's 26 Aug interview describes more than 8 GW of present Romanian PV across utility and prosumer segments and forecasts more than 5 GW of additions through end-2028. These are industry-association estimates, not an official commissioned-capacity register. Their most useful implication is the scale of the coming integration requirement. [S18]
Integrated projects are replacing stand-alone PV as the commercial brief.
Servelect forecasts 2026 revenue above €20m and reports work combining PV, batteries, heat pumps and EV infrastructure across public and private clients. This is self-reported company demand evidence rather than national market-size data, but it is consistent with the broader shift toward integrated energy systems. [S20]
07 / Forward view
27 Aug–2 Sep: watch the return of supply, not just the level of demand.
At the research cut-off, the 27 August PZU result was already known day-ahead and therefore functions as a starting condition rather than a forecast: base 917.15 RON/MWh, 08:00–17:00 proxy 634.32 RON/MWh, low PT15 326.48 RON/MWh and no negative PT15 intervals. The next regime change will depend on the interaction of nuclear availability, hydrology, solar conditions, load and evening flexibility. [S02]
Directional scenarios · no numeric probability assigned
Forward view: 27 Aug–2 Sep 2026
Numeric probabilities are intentionally not assigned because nuclear restart timing, hydrology and weather-driven renewable output are not calibrated here to a forecasting model. The scenarios instead define observable conditions that would confirm or invalidate each path.
High absolute prices coexist with a persistent daylight discount.
The central case is continued separation between absolute scarcity and solar profile risk. Weekdays can remain expensive if firm domestic generation stays constrained, while sunny or low-load intervals still produce a meaningful discount to base.
- Assumption: no immediate full normalisation of the Cernavodă/hydrological constraint.
- Confirmation: 19:00–22:00 net imports remain material and PZU base remains elevated.
- Solar signal: 08:00–17:00/base ratio broadly stays between the extreme weekend compression and scarcity-supported weekday levels seen this week.
- Storage signal: several-hundred-MW evening storage output remains visible in the public feed.
Scarcity continues to support both solar-hour value and storage optionality.
From the commercial perspective of existing solar and flexible assets, continued tight firm supply would keep absolute daylight prices stronger than a normal late-summer abundance regime while preserving significant evening value.
- Condition: nuclear output remains absent or only partially returns and hydro remains constrained.
- Solar implication: daylight proxy/base ratio stays high on working days despite continued PV output.
- BESS implication: evening system need remains visible, preserving multiple monetisation pathways.
- System caveat: this is an “upside” only for asset price support; it is not an upside for national power-system cost or security.
Firm supply returns into sunny, lower-load hours and daylight compression deepens.
A Cernavodă restart and/or hydrological improvement could reduce the scarcity premium at the same time that solar remains strong. That would improve system adequacy while potentially worsening merchant solar's relative capture profile.
- Condition: nuclear generation reappears, imports ease and renewable output remains healthy.
- Warning: 08:00–17:00/base ratio falls below 50% on multiple delivery days.
- Escalation: PT15 prices return repeatedly to zero or negative territory.
- Commercial response: increase emphasis on contracted offtake, curtailment treatment, co-located storage and connection-envelope optimisation.
Analyst watch trigger for 08:00–17:00 proxy/base ratio on repeated days; not an official threshold.
Watch repeated 19:00–22:00 net import readings above this level in retained operating observations.
Track frequency and duration of reported evening storage output at or above the levels visible this week.
Official restart status is the most obvious regime-change indicator for the next briefing.
Standalone BESS call scheduled to open. The €150m scheme was analysed previously; monitor submissions and competitive aid/MWh behaviour rather than restating eligibility.
08 / Implications by audience
What this week changes in a real decision process.
The common theme is to stop treating MW as the sufficient unit of analysis. Time, MWh, permitted export, operating status, contract structure and evidence class now materially alter the commercial conclusion.
Underwrite two price regimes, not one weekly solar average.
The same seven-day period produced a 79.2% weekday solar-window/base ratio and 23.9% weekend ratio. Merchant models should therefore stress low-load abundance separately from scarcity-supported weekdays, including zero-price and curtailment scenarios even when annual average prices appear strong. A co-located BESS should be valued against avoided solar exposure, grid-envelope benefit and market services—not a single arbitrage spread.
Design around the service stack and connection node before optimising duration.
Public evidence shows substantial evening system need and several-hundred-MW storage output, but not realised margins. Revenue diligence should separate DAM/ID energy shifting, balancing, reserves, congestion/curtailment value and grid-capacity value. Do not infer a 2-hour or 4-hour commercial strategy from an MWh headline when MW, SoC limits or market commitments are missing.
Make export envelope a first-class design variable.
MVM's Arcuș disclosure shows installed capacity and stated maximum export can differ, while WALDEVAR's Dobrești project includes dedicated 110 kV infrastructure. ANRE's draft now explicitly recognizes that storage can reduce peak evacuation. Connection modelling should therefore compare PV-only export maxima with hybrid dispatch, transformer ratings, reinforcement milestones and operating constraints at the actual node.
Discount pipeline MW according to maturity and scope.
“Connected” can include test stages; an ATR can relate to post-2030 delivery; establishment authorisation is not commissioning; and a company portfolio is not operating capacity. Investment committees should maintain separate buckets for operating, energised/testing, construction, authorised, ATR and announced capacity, with independent dates and probability assumptions rather than one aggregate pipeline figure.
Recalculate storage against self-consumption after the compensation transition.
ANRE's proposed transition away from new long-dated quantitative carry-forward increases the relevance of matching generation to on-site load. But a subsidised battery is not automatically economic: use the site's 15-minute or hourly load, import price, export remuneration, inverter limitations, cycle warranty and expected usable capacity. Vega shows the industrial logic; household economics remain site-specific.
Sell a defined electrical function, not an undifferentiated battery headline.
Procurement specifications increasingly need explicit MW, MWh, AC/DC boundary, warranted usable energy, round-trip efficiency, degradation, grid-code compliance, transformer and substation scope, EMS/SCADA capability, response time, auxiliary consumption and service warranty. The ELCO example also shows why partial civil/electrical contract value must not be presented as the capex of the full BESS.
09 / Source register and method
What is evidenced, what is derived, and what remains unknown.
This briefing freezes evidence at 26 Aug 2026, 23:59 EEST. Later revisions to live pages or subsequent project announcements are outside the research window.
Operational and market series are kept separate.
- The publication dataset supplied for this issue contains 168 local-hour records covering the complete 20–26 Aug window.
- Each retained local-hour value is the arithmetic mean of public operational snapshots stored inside that local hour; missing hours are not interpolated.
- The weekly 5,579 MW consumption and 994 MW solar values are taken from the time-normalised 168-hour register, not from a sample-weighted average of raw daily snapshots.
- Daily market-summary values on SolarIndustry's data-history page are arithmetic means of retained observations and expose their raw sample counts. They are not treated here as settlement-metered energy shares.
- OPCOM PZU base and PT15 outcomes are separate market evidence. The 08:00–17:00 proxy is an unweighted price series.
- Derived figures in this report use transparent arithmetic from the cited values; no missing price or operating interval has been filled.
Several attractive headline numbers were deliberately not promoted to core evidence.
- No true solar capture price is published because PT15 generation aligned to the relevant market solar scope is not available in the retained evidence.
- No battery margin is estimated from price spreads; asset-level charging, losses, degradation, ancillary revenues and dispatch positions are unknown.
- The public solar operational line does not include all prosumer production. Industry estimates for prosumer storage were not used as national storage KPIs where power/energy definitions could not be reconciled.
- Transelectrica's technology components sum to 2,515 MW while its stated total is 2,514 MW. The one-MW source discrepancy is preserved and labelled.
- Formal inauguration stories are not counted as new capacity unless commissioning or new connection occurred in the review window.
- Very large early-stage project headlines without sufficiently strong primary evidence, construction maturity or clear connection pathway are excluded from the quantitative system baseline.
- Publication date is not treated as event date: Eurowind's 2,307.4 MW ATR disclosure was published 26 Aug but the approvals were obtained in June.
| ID | Organisation | Use in this briefing | Evidence class | Link |
|---|---|---|---|---|
| S01 | SolarIndustry.ro | Retained Transelectrica operating observations; hourly method; daily summaries; publication dataset freeze for 20–26 Aug. | Derived platform evidence | Data History |
| S02 | OPCOM | Official PZU PT15 prices, daily base outcomes and traded-volume reference. | Primary / market operator | PZU results |
| S03 | SolarIndustry.ro | Prior-week analytical baseline and continuity check to avoid repeating the 13–19 Aug briefing. | Prior research | Previous briefing |
| S04 | Transelectrica | 2,514 MW 2026 connections, technology split, Părău BESS, 989 MW storage stock at 1 Aug, maturity caveat and operator year-end connection estimate. | Primary / TSO | 20 Aug press release |
| S05 | Economica.net | 13:04 capture of 3,453 MW dispatchable PV and contemporaneous Transelectrica system context. | Secondary / underlying TSO feed | 20 Aug report |
| S06 | Nuclearelectrica | Status of both Cernavodă units on 24 Aug. | Primary / issuer | Current report |
| S07 | ANRE | 24 Aug consultation status and 30-day comment period for financial-guarantee procedure. | Primary / regulator | Consultation page |
| S08 | ANRE | Rationale for co-located storage exemption, 30 EUR/kW guarantee, peak-export and network-capacity logic. | Primary / regulator memo | Approval memorandum |
| S09 | ANRE | 20 Aug prosumer quantitative-compensation transition consultation and 31 Aug comment deadline. | Primary / regulator | Consultation page |
| S10 | Rompetrol Rafinare | Vega Ploiești 4.8 MW PV + ~9 MWh storage, capex, funding, self-consumption and implementation date. | Primary / issuer | Issuer release |
| S11 | Scatec | Urleasca financing/construction and 190 MW Dobrun & Sadova solar construction context. | Primary / issuer | 20 Aug release |
| S12 | WALDEVAR via News.ro | Dobrești 95 MWp PV + 220 MWh BESS, 110 kV infrastructure, construction disclosure and project yield estimate. | Commercial self-report carried by press | 25 Aug report |
| S13 | Energynomics / ELCO | Curtici 55 MW BESS external civil/electrical contract scope and €1.6m value limitation. | Secondary + company disclosure | 20 Aug report |
| S14 | MVM via Bursa | Arcuș establishment authorisation, 24.6 MW installed and 21.21 MW stated maximum export. | Company release carried by press | 25 Aug report |
| S15 | Eurowind via Economica | 2,307.4 MW ATR disclosure, June approval date, Mănești 49 MW PV+BESS and post-2030 network dependency. | Company release carried by press | 26 Aug report |
| S16 | Radio România Actualități | 26 Aug Casa Verde Baterii consultation meeting and 35,000–40,000 beneficiary ambition. | Public broadcaster / official interview | 26 Aug report |
| S17 | Agenda Construcțiilor / Aukera | Aukera Romanian storage programme, Gura Ialomiței project status and >1 GW company ambition. | Industry interview / self-report | 26 Aug interview |
| S18 | RPIA via Agenda Construcțiilor | Association view of current PV scale, integration constraints and >5 GW addition forecast through end-2028. | Industry association | 26 Aug interview |
| S19 | AGERPRES | Standalone BESS call calendar: 1 Sep–30 Oct; €150m allocation. Used only as forward administrative timing because scheme economics were covered in the prior issue. | Public news agency / government statement | Funding calendar |
| S20 | Agenda Construcțiilor / Servelect | Company revenue forecast and integrated PV+BESS/C&I project demand signal. | Commercial self-report | 21 Aug report |
| S21 | Economica / Transelectrica data | 1 Aug storage-energy reference of 1,975 MWh alongside 989 MW. | Secondary / underlying TSO data | 4 Aug reference |