"Hayk's Arrow" Armenian Strategic Center

Azerbaijan

Azerbaijan’s official balances show a long decline in oil output, a different gas trajectory and continuing fossil-fuel dominance at home.

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Azerbaijan’s official balances show a long decline in oil output, a different gas trajectory and continuing fossil-fuel dominance at home. Renewable electricity is growing from a smaller base, making export availability and system transformation separate questions for Armenian strategic analysis.

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Sector detail

10

The 2025 production table distinguishes fuel-fired utilities, fuel-based autoproducers and renewable technologies. The separate electricity balance then tracks trade, losses and final consumption. All output and balance values below are GWh, not capacity in MW.

Sector detail
IndicatorValue and reference period
Fuel-fired plants and CHPMain fuel-fired electricity and combined heat-and-power category; excludes separately listed fuel-based autoproducers.22,878.3 GWh2025Reported result[80]
Fuel-based autoproducersSeparately reported electricity generation by autoproducers working with fuel; add to the main fuel-fired category only when computing a broader fuel-based share.1,967.4 GWh2025Reported result[80]
Hydroelectric generationReported annual hydroelectric production, not hydro installed capacity.2,842.5 GWh2025Reported result[80]
Wind generationWind electricity produced during 2025; later project openings are not included as assumed annual output.172.3 GWh2025Reported result[80]
Solar generationReported 2025 solar electricity production, separate from project MW announcements.600.4 GWh2025Reported result[80]
Waste-incineration electricityWaste-incineration category; not reclassified here as wholly renewable because the fossil/biogenic split is not supplied.222.1 GWh2025Reported result[80]
Final electricity consumptionFinal consumption in the electricity balance; excludes separately reported energy-industry own use and network losses.21,519.6 GWh2025Reported result[69]
Network lossesTransmission losses 392.0 plus distribution losses 1,883.1 GWh; not plant own use.2,275.1 GWh2025Reported result[69]
Electricity importsAnnual inward electricity flow in the national balance; not primary-energy imports or monthly availability.177.4 GWh2025Reported result[69]
Electricity exportsAnnual outward electricity flow; the source records exports with a minus sign in its supply balance, shown here as a positive outward quantity.1,148.1 GWh2025Reported result[69]

Azerbaijan’s electricity baseline remains predominantly fuel-based when the separately reported autoproducers are included. Wind and solar output should be tracked as delivered annual energy rather than inferred from newly opened or announced MW. For Armenia, this distinction prevents a headline renewable project from being mistaken for a near-term change in Azerbaijan’s entire energy system. A practical monitoring sheet should show commissioning dates, actual monthly production, fuel-fired output and domestic demand alongside export flows. [80]

The balance also separates production from electricity available to final users. Network losses and energy-industry own use mean that gross generation is not interchangeable with customer supply. Armenia should therefore compare like balance stages before drawing efficiency conclusions, and request route-specific commercial terms before considering any future exchange. The observed annual exports establish that an outward flow occurred; they do not establish an Armenian purchase option, an open interconnector, a tariff, a winter guarantee or agreed political and contractual conditions. [69]

Scope and limitations

The plant-type table totals 28,683.0 GWh. Fuel-fired utilities plus fuel-based autoproducers equal 24,845.7 GWh; this is a derived broad fuel-based category, not a gas-only series. Dashes in other source categories are not silently converted into measured zeros. Annual trade does not identify seasonal capacity available to Armenia. [80]

Compare Armenia, Azerbaijan and Georgia
122 full documents checked + 6 checked excerpts

What this means for Armenia

Priority and sequence

Azerbaijan's approved financing for grid reinforcement, officially reported wind-plant opening and continuing gas investment create three conditional Armenian exposures.

Azerbaijan's approved financing for grid reinforcement, officially reported wind-plant opening and continuing gas investment create three conditional Armenian exposures. Regional gas tightness could reduce flexible supply options; neighbouring electricity availability can vary by hour; realised generation and transmission investments can change competition for markets and network access. None establishes firm energy available to Armenia. The robust response is to identify Armenia's difficult-period service requirement, then price efficiency, flexibility and lawful exchange against it. This remains useful whether neighbouring expansion succeeds or is delayed. Matching another country's announced megawatts, or expecting its resources to disappear quickly, would bypass the delivery and reliability questions that should decide an Armenian investment. [126][128][125]

First priorityTest seasonal adequacy before new dependence

Why this comes first

Prioritise seasonal-stress because it defines the service gap that the other three actions must solve. It should end in a dispatch, maintenance, contracting or demand decision, not another report. Starting a foreign-supply negotiation or equipment purchase before identifying the critical hours risks buying cheap annual energy that does not protect essential demand. This order also preserves bargaining room: Armenia can compare an offer with a documented domestic alternative. [65][76][80]

Proposed sequence

Proposed horizons run from authorisation. Later stages depend on the conditions below; these are analytical choices, not adopted deadlines or funding commitments.

  1. First 90 days

    In the proposed first 90 days, have authorised Armenian operators reconcile demand, planned outages, reserves and usable import arrangements. Test a combined adverse period and assign each uncovered service requirement to a responsible decision-maker. Keep security-sensitive operating detail restricted; publish only the policy-level assumptions and resulting categories of action. [65][76][123]

  2. 3–12 months

    During the proposed three-to-twelve-month phase, procure a bounded public-building efficiency or demand-reduction trial against the identified gap. Establish comfort, safety and weather-adjusted baselines. Compare conditional regional offers using delivered cost, interruption, balancing and settlement terms; reject an assumed direct Azerbaijan–Armenia connection as the basis of the comparison. [76][80][128]

  3. Beyond 12 months

    After twelve months, scale only verified service improvements and apply the same adverse-period test to major Armenian investments. Update assumptions when a neighbouring asset is actually commissioned or access is contracted. Preserve options that retain domestic value if foreign projects are late; incorporate recurring maintenance and workforce costs before committing to expansion. [124][125][127]

Main constraint

The binding constraint is firm capability in the relevant period, including operators' authority and counterpart obligations. Annual output, financial close or a transmission loan cannot establish Armenian emergency access. The first exercise mainly needs qualified operating and commercial staff; later procurement needs a funded baseline, verification and maintenance process. These are different resource commitments. A signed inexpensive energy offer should not displace reliability reserves unless its interruption conditions are acceptable. [80][109][128]

When another option would be better

Advance efficiency-procurement immediately where a recent Armenian audit already establishes a safe, measurable and financeable saving; repeating the diagnosis would waste time. An imminent outage instead requires the authorised operator's established continuity response before a research exercise. Regional exchange should lead only when lawful capacity, settlement and reliability are already confirmed and it outperforms the domestic alternative. None of these exceptions makes Azerbaijani project targets a delivery guarantee. [76][80][125]

Exports create relationships, not unlimited supply

Azerbaijan's gas sales connect it with European buyers, Türkiye and Georgia, while domestic households and power generation compete for the same physical resource. For Armenia, this network matters even without direct purchases: a regional shortfall or tighter contract commitments can affect neighbouring power availability, transport costs and bargaining conditions. The ministry's gross gas extraction is not a pool of uncommitted export supply. Any Armenian proposal based on a large annual production number would therefore risk confusing national output with deliverable seasonal capacity. The useful question is whether a specific transaction adds reliable supply at the time Armenia needs it, without creating a new single point of dependence or displacing an existing backup. [123][65][76]

Field investment sets a changing regional baseline

The compression project and associated offshore contracts demonstrate investment to sustain and extend an established gas field, while oil output has declined over a longer period. Armenia should not base long-lived infrastructure choices on either imminent Azerbaijani resource exhaustion or permanent cheap abundance. Construction, reservoir performance, domestic demand and buyer commitments all intervene between an investment decision and an exportable volume. The implications for Armenia are primarily commercial and strategic: preserve options, negotiate against a documented supply case and avoid paying for infrastructure that becomes useful only under one optimistic production path. Published contract awards improve confidence that work is progressing, but their target dates do not provide an Armenian delivery guarantee. [36][124][125]

A cleaner export system can remain gas-centred

The planned Shafag–Sangachal arrangement links renewable generation to reduced gas use at an export terminal. If realised, it can strengthen Azerbaijan's commercial position while lowering particular operating emissions; it is not necessarily a retreat from hydrocarbon exports. Armenia's response should therefore distinguish its own energy security objectives from a competition over announced renewable megawatts. Reducing avoidable demand, improving system flexibility and buying dependable balancing services can be valuable even if regional export patterns barely change. Conversely, assuming that neighbouring renewable construction automatically produces cheap surplus power available to Armenia ignores network access, timing, domestic dispatch and contracts. Armenia gains most from options it can use under several regional supply outcomes. [125][80][109]

Research

8 chapters

Oil decline and a different gas trajectory

The statistical energy-balance series reports crude oil including condensate at 27.6719 million tonnes in 2025, compared with 50.8382 million in 2010. The same product table records natural gas at 38.8805 billion cubic metres in 2025. These are the quantities used in this balance convention; they should not be combined silently with gross extraction figures from another reporting system. The oil decline is visible across the series rather than inferred from one year. [36][78][79]

For Armenia, the meaningful strategic question is how changing oil and gas flows affect export earnings, investment needs and relationships with buyers. More gas does not automatically offset less oil in revenue or bargaining power: prices, processing needs, transport commitments and domestic use intervene. Separate product accounts, extraction tables and enterprise indicators make those channels visible and discourage treating hydrocarbons as one unchanged pool of national resources. [2][51][65]

Domestic energy balance

Total energy supply in the official series declined from 18.4808 million tonnes of oil equivalent in 2024 to 17.8578 million in 2025. Gaseous fuels accounted for 68.7% and liquid fuels for 28.9% of the 2025 total. This describes the domestic energy mix, not the electricity-generation mix or the share of each fuel in export revenue. The distinction exposes a strongly fossil-based system despite the country’s renewable investment agenda. [9][41][35]

The balance also records transformation, energy-industry own use, losses, stock changes and statistical differences. Each item changes what remains available for final users or export. For Armenian analysis, lower domestic supply should therefore be investigated as a combination of activity, efficiency and accounting movements rather than assumed to indicate shortage. Comparing adjacent annual balances can identify which component changed before assigning an economic or political explanation. [45][46][44]

Electricity production and system capacity

The electricity account reports 28.683 billion kWh generated in 2025, compared with 28.4126 billion in 2024. Hydroelectricity contributed 2.8425 billion kWh, solar 600.4 million and wind 172.3 million. The account also separates combined heat-and-power generation and electricity plants. Installed megawatts in the capacity table measure potential output at a point in time; annual kWh measure delivered production and cannot be substituted for capacity. [69][80][109]

Armenia’s relevant comparison is the availability of reliable power and possible exchange, not which country announces the largest plant. Generation composition, imports, exports and domestic demand constrain the usable surplus. Seasonal patterns and network connections would need additional operator-level evidence before a supply commitment could be assessed. The historical capacity series nevertheless helps separate additions to the physical system from changes in utilisation of existing assets. [3][48][67]

The presidency records the official opening of the 240 MW Khizi–Absheron wind plant on 8 January 2026. This is a dated physical-project milestone beyond a financing announcement. Installed capacity and an inauguration are nevertheless different from realised annual electricity output; a full-year performance claim requires the corresponding generation series rather than the plant’s projected yield. [126]

End users and the demand for fuel

Final-use accounts record 5.5805 billion cubic metres of natural gas consumed in 2025, down from 5.8427 billion in 2024. The corresponding series reports 1.6156 million tonnes of motor gasoline and 1.8309 million tonnes of diesel in 2025. Industry, transport, construction, agriculture, households and services have separate accounts, allowing demand changes to be traced to activities rather than attributed to the entire economy indiscriminately. [49][74][76]

For Armenian researchers, this matters because export availability is linked to competing domestic uses. Reducing power-sector fuel use, improving buildings or changing transport consumption have different costs and timelines. Regional household gas and electricity tables can also reveal uneven service demand, while industrial consumption connects energy policy to production. These are concrete channels through which an energy-exporting neighbour can experience internal constraints despite a large resource base. [84][85][70]

Domestic gas demand competes with export availability through a physical rather than merely diplomatic mechanism. Household consumption rose from 2.751 billion cubic metres in 2015 to 4.006 billion in 2025. Gas also fuels electricity generation, so cold-weather heating and power requirements can tighten availability together. Storage and dispatchable generation can shift timing, while an annual surplus alone cannot establish winter delivery capability. For Armenia, any future energy exchange would therefore need credible seasonal delivery arrangements and fallback supply, not simply a favourable annual national balance. [76][65][38][48]

Energy trade and exportable surplus

The source library includes separate accounts for exports, imports, international bunkers and non-energy uses. That structure matters because gross production, domestic supply and export delivery are different totals. Older fuel balances and the 2007–2025 product series document the transition from earlier flows to the present mix. A defensible export assessment must keep product units and accounting boundaries consistent rather than adding tonnes, cubic metres and electricity together. [64][37][39]

For Armenia, trade should be connected to the foreign-policy observatory through named buyers, infrastructure and contractual status. A surplus in an energy balance is a material resource but not proof of an available commercial route into Armenia. Conversely, reduced oil volumes do not erase established investment and pipeline relationships. The evidence supports examining the composition of external ties, while separate agreements are needed to establish actual market access. [87][18][100]

The Energy Ministry’s operational release places 2025 gas sales abroad at 25.2 billion cubic metres: Europe 12.8, Türkiye 9.6, Georgia 2.3 and Syria 0.5. These buyers provide different combinations of revenue, transit cooperation and diplomatic relationships. Europe is a regional destination category, not a single buyer or contract. The ministry’s 51.5 billion cubic metres of gross production is different from the statistical energy-balance gas quantity: associated gas, reinjection and reporting conventions intervene. Treating the gross total as freely exportable would greatly overstate commercial flexibility. [123][64]

Renewables, efficiency and investment

The 2025 balance assigns solar energy 0.3% and wind 0.1% of total energy supply, while the electricity efficiency table puts all renewable generation at 13.4% of electricity production. The denominators differ: hydropower contributes much more to electricity than solar or wind does to total energy. This explains why visible renewable growth can coexist with a predominantly fossil-fuel national balance without either statement being inconsistent. [8][7][5]

Investment and industrial-intensity tables provide a second test of transition: whether money changes output per unit of energy, not merely installed capacity. For Armenia, competition in regional electricity markets will depend on cost, grid integration and reliable delivery as well as renewable branding. The useful research distinction is between commissioned generation, measured energy savings and announced projects; this dataset establishes the first two only where recorded in the underlying annual accounts. [14][6][16]

External context: the IEA’s 2023 country profile places oil and gas within the economy’s historical development and explains the energy-accounting framework. The World Bank’s January 2025 strategy supports renewable investment and energy transmission. These external assessments frame the transition challenge; their older baselines and programme intentions do not independently validate every 2025 national statistic or establish that planned assets have entered operation. [121][122]

Masdar’s 445 MW Bilasuvar solar project reached financial close in November 2024, but its project page still lists construction when checked on 1 November 2026 and supplies no completion year. Forecast annual generation above 961 million kWh is therefore kept separate from measured national solar output. Financial close establishes a funding milestone, not delivery of the forecast electricity. [127]

Mature fields and committed development

ACG remains a major oil source: the ministry assigns it 16.2 million tonnes in 2025, against national oil and condensate output of 27.7 million. Shah Deniz supplies a different system, with 27.9 billion cubic metres of gross gas in the ministry’s account. bp’s June 2025 decision for the USD2.9 billion Shah Deniz Compression project addresses low-pressure resources and extends recovery from an established field; its announced first-gas target is 2029. Compression is therefore an investment in sustaining and extending the resource base, not proof of an immediate new export plateau. bp’s 29.999% participating interest in that decision also illustrates consortium ownership rather than exclusive national operational control. [123][125]

Implementation has advanced beyond a political announcement: Saipem’s October 2025 release records approximately USD700 million of awarded offshore contracts with SOCAR-affiliated BOS Shelf partners, including a 19,000-ton compression platform and about 26 kilometres of connecting pipelines. It targets completion in 2029. Awarded engineering work is a stronger commitment than a memorandum, but the contractor’s planned schedule is not an operating result. The construction chain also spreads economic benefits and delivery risks across foreign engineering firms, domestic fabrication, specialist vessels and finance. For Armenia, this makes abrupt assumptions about either permanent abundance or imminent resource exhaustion equally weak. [124][14]

What the electricity transition changes

The planned 240 MW Shafag solar project and Sangachal electrification show a specific transition mechanism: power enters AzerEnerji’s grid and equivalent electricity supplies the terminal, potentially freeing gas previously burned on site. This is not a dedicated physical solar wire or a guaranteed round-the-clock solar supply. The 2025 generation table still records 22.878 billion kWh at fuel-fired power and combined-heat plants, plus 1.967 billion from fuel-fired autoproducers, against total generation of 28.683 billion. Solar and wind therefore complement a predominantly fuel-based system. Their strategic value depends on realised output, network flexibility and reduced fuel use as well as installed megawatts. [125][80][109]

AZURE’s USD 173.5 million IBRD loan was approved on 27 March 2025 for transmission reinforcement and renewable integration. The release targets grid stability for 1.8 GW and expects to mobilise USD 384 million of private investment. These are project objectives and expected mobilisation, not completed generation capacity or verified private disbursements. The grid constraint remains distinct from building power plants. [128]

Risks and opportunities

Risks

Declining oil output and complex offshore development create a continuing replacement-investment requirement; a contracted project can still encounter scheduling or delivery constraints. [36][124]

Domestic heating and power demand limit flexible gas availability; annual production totals cannot ensure an additional buyer’s seasonal supply. [65][76][80]

Opportunities

Renewables and terminal electrification can release fuel gas and reduce operating emissions if the projects deliver their planned generation and grid integration. [125][8]

Regional electricity exchange could give Armenia an additional balancing option if physical interconnection, commercial terms and dependable access are established. [64][69]

Conditional scenarios

These scenarios explore how documented drivers could affect Armenia. They are conditional analytical paths, not predictions or assigned probabilities.

More flexible exchange

Conditional scenario, not a forecast: if renewable projects and grid integration reduce domestic gas burn, Azerbaijan could gain export flexibility. Armenia might benefit from negotiated electricity exchange only with usable interconnection and enforceable seasonal terms; new installed capacity alone would not deliver that access. [125][80][69]

Delivery margins tighten

Conditional scenario, not a forecast: if offshore work is delayed or domestic winter requirements rise, new export commitments could face tighter delivery margins. Armenia would need diverse supply and balancing options before relying on any future Azerbaijani energy arrangement. [124][76][123]

What to watch

Compare oil decline and gas output under unchanged definitions before assessing export revenue implications. [36]

Track renewable production, energy intensity and domestic demand alongside new-project announcements. [8][49]

Source library

122 checked source documents · 6 checked excerpts
Coverage and methodology

The count includes distinct documents whose content was retrieved and checked for relevance to this profile. Translations, duplicate links and generic homepages are excluded. A document may support more than one topic when its content is relevant to each. Historical documents retain their original dates; they do not establish that a project or policy remains unchanged today.

Sources labelled “Excerpt checked” were reviewed only in the retained relevant passage. They can support the cited claim but are excluded from the full-document total.

Filters

128 / 128 · Original sources

Filters use the source date recorded in this library. Indicator reference periods are shown separately.

  1. Main indicators of the enterprises operating in the energy sector
    State Statistical Committee of Azerbaijan · Undated · Sources checked: 1 Nov 2026
  2. Main indicators of enterprises operating in crude oil and natural gas production and related services
    State Statistical Committee of Azerbaijan · Undated · Sources checked: 1 Nov 2026
  3. Main indicators of enterprises engaged in the production and distribution of electricity, heat and gas
    State Statistical Committee of Azerbaijan · Undated · Sources checked: 1 Nov 2026
  4. Main indicators of enterprises manufacturing petroleum products
    State Statistical Committee of Azerbaijan · Undated · Sources checked: 1 Nov 2026
  5. Energy consumption indicators
    State Statistical Committee of Azerbaijan · Undated · Sources checked: 1 Nov 2026
  6. Energy capacity (GDP, PPP)
    State Statistical Committee of Azerbaijan · Undated · Sources checked: 1 Nov 2026
  7. Energy efficiency indicators
    State Statistical Committee of Azerbaijan · Undated · Sources checked: 1 Nov 2026
  8. Renewable energy supply
    State Statistical Committee of Azerbaijan · Undated · Sources checked: 1 Nov 2026
  9. Use of energy types in total energy supply
    State Statistical Committee of Azerbaijan · Undated · Sources checked: 1 Nov 2026
  10. Final consumption of energy by types of economic activity
    State Statistical Committee of Azerbaijan · Undated · Sources checked: 1 Nov 2026
  14. Investments in fixed assets directed to the energy sector, million manats
    State Statistical Committee of Azerbaijan · Undated · Sources checked: 1 Nov 2026
  18. Energy balance in 2007-2025
    State Statistical Committee of Azerbaijan · 2025 · Sources checked: 1 Nov 2026
  19. Energy balance by products in 2007
    State Statistical Committee of Azerbaijan · Undated · Sources checked: 1 Nov 2026
  20. Energy balance by products in 2008
    State Statistical Committee of Azerbaijan · Undated · Sources checked: 1 Nov 2026

Electricity generation

Annual electricity output in the same statistical series.

Generated electricity is an energy volume. It is distinct from installed capacity in MW and from exports.

Electricity generation · Billion kWh · 2024–2025
ObservationValue · Billion kWhReference periodStatusSources
202428.41262024Reported result
202528.6832025Reported result

Electricity production: a common 2025 baseline

Sources checked 1 Nov 2026

The comparison uses the same calendar year and separates annual output from capacity, primary energy and trade. Shares are calculated from each source’s reported generation total; national coverage differences remain visible.

On smaller screens, scroll the table sideways to compare all three countries.

Compare Armenia, Azerbaijan and Georgia
Indicator🇦🇲 Armenia🇦🇿 Azerbaijan🇬🇪 Georgia
Reported annual electricity generationGWhRead with stated qualifications10,010.3 GWh2025EstimateSource28,683.0 GWh2025Reported resultSource13,837.7 GWh2025Reported resultSource
Thermal / fuel-based share% of annual generationRead with stated qualifications33.57%2025EstimateSource86.62%2025Reported resultSource20.00%2025Reported resultSource
Hydro share of reported generation% of annual generationRead with stated qualifications21.04%2025EstimateSource9.91%2025Reported resultSource79.40%2025Reported resultSource
Wind share of reported generation% of annual generationRead with stated qualifications0.01%2025EstimateSource0.60%2025Reported resultSource0.57%2025Reported resultSource
Solar share: identified coverage% of annual generation where separately identifiedNot directly comparable16.25%2025EstimateSource2.09%2025Reported resultSourceNot separately identified2025Reported resultSource

Definition and coverage

Reported annual electricity generation

Headline physical electricity production, not primary energy, installed capacity, net customer supply or export capacity. Same year and physical energy unit, but national coverage is not fully harmonized: Armenia includes estimated autonomous onsite use, Azerbaijan separates fuel autoproducers, and Georgia uses ESCO balance categories with a small unresolved residual.

Reading for Armenia

Armenia’s smaller annual total makes outage timing and reserve sharing material; these totals do not establish firm regional supply available to it.

Thermal / fuel-based share

Thermal or fuel-based generation divided by each country’s headline generation. Azerbaijan includes main fuel-fired plants and fuel autoproducers; this is not a harmonized gas-only indicator. Same year and physical energy unit, but national coverage is not fully harmonized: Armenia includes estimated autonomous onsite use, Azerbaijan separates fuel autoproducers, and Georgia uses ESCO balance categories with a small unresolved residual.

Reading for Armenia

Armenia should compare fuel exposure and winter dispatch needs separately from renewable-project MW; no annual share alone measures fuel-supply security.

Hydro share of reported generation

Hydroelectric GWh divided by each country’s reported total electricity-generation GWh, with national coverage qualifications retained. Same year and physical energy unit, but national coverage is not fully harmonized: Armenia includes estimated autonomous onsite use, Azerbaijan separates fuel autoproducers, and Georgia uses ESCO balance categories with a small unresolved residual.

Reading for Armenia

Georgia’s high hydro share makes hydrology and seasonal matching central to an Armenian import case; it does not guarantee a winter surplus.

Wind share of reported generation

Reported wind GWh divided by each country’s headline generation; values are production shares, not installed-capacity shares or forecasts. Same year and physical energy unit, but national coverage is not fully harmonized: Armenia includes estimated autonomous onsite use, Azerbaijan separates fuel autoproducers, and Georgia uses ESCO balance categories with a small unresolved residual.

Reading for Armenia

The low observed shares make actual commissioning and measured output more useful than project announcements when tracking a regional wind transition.

Solar share: identified coverage

Reported solar output divided by headline generation for Armenia and Azerbaijan. ESCO’s displayed 2025 balance does not separately identify solar generation, so no Georgian share is calculated. Partial numeric comparison only. Armenia 1,626.8/10,010.3 and Azerbaijan 600.4/28,683.0; national coverage differs. Georgia is unclassified in this table, not zero; the 4.6 GWh reconciliation residual cannot fill that gap.

Reading for Armenia

Armenia’s reported solar output is already material to annual energy, but an annual share cannot establish evening adequacy. Georgian classification is missing here, so a three-country solar ranking would be misleading.

Scope and limitations

Same year and physical energy unit, but national coverage is not fully harmonized: Armenia includes estimated autonomous onsite use, Azerbaijan separates fuel autoproducers, and Georgia uses ESCO balance categories with a small unresolved residual.

Georgia’s 4.6 GWh computed reconciliation residual is not assigned to solar or another technology. Missing classification is not zero production. Armenian autonomous onsite use is an estimate.

No generation total or share establishes a supplier, contract, open border transfer capacity or firm electricity deliverable to Armenia in a particular hour.

Several countries or indicators can share one underlying data release. Multiple source links do not mean independent confirmation.

Earlier evidence snapshots

2 · Evidence records

These dated records preserve the earlier research edition. Later source releases and statistical revisions are reflected in the detailed analysis above.

Filters

2 / 2 · Evidence records

Announced / planned

Investment decision for 240 MW Shafag solar plant

Reference period: Investment decision in 2025; announced construction timetable to 2027–2028

On 2 June 2025, final investment documents were signed for the 240 MW Shafag solar plant and Sangachal terminal electrification. The release anticipated solar construction through mid-2027; it does not establish that either project is operational.

Details and sources

Original sources (1)

Documented

Ministry reports 12.8 bcm of gas exports to Europe

Reference period: Calendar year 2025; undated ministry page checked 1 November 2026

Azerbaijan's Energy Ministry reports 12.8 billion cubic metres of natural gas exports to Europe in 2025. The geographical category is Europe, not exclusively the EU; these are reported annual flows, not pipeline capacity.

Details and sources

Original sources (1)

Coverage and methodology

This is a curated starting collection, not an exhaustive country database or a live feed. Each record identifies its reference period and links to original evidence. “Announced” does not mean funded, ratified or operational; those distinctions are stated in the text. Armenia implications are editorial analysis, not source quotations. Census counts, population estimates and forecasts must not be treated as interchangeable. Source-check dates do not change the underlying data period.

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