The Middle East and North Africa region installed 12.2 GW of solar in 2025 alone — the largest single-year addition in the region’s history. Total installed solar capacity across the Middle East surpassed 30 GW in 2026. Saudi Arabia leads with approximately 12 GW of installed capacity, followed by the UAE at around 6.7 GW, Egypt at 3.2 GW, Jordan at 2.1 GW, Oman at 1.6 GW, and Qatar at 1.7 GW. The region consistently produces the world’s lowest solar LCOE bids — the UAE’s Al Dhafra project set a world record tariff of approximately 1.35 cents/kWh in 2023 — driven by the combination of high irradiance, low land costs, and government-backed procurement frameworks.
This pillar covers compliance requirements across eight Middle East markets: UAE, Saudi Arabia, Jordan, Egypt, Oman, Israel, Qatar, and Kuwait. Each country operates under distinct regulatory authority, connection rules, system size limits, and export compensation mechanisms. Getting the country-specific compliance pathway right before breaking ground is the difference between a project that connects on schedule and one that stalls for months waiting for re-approval.
UAE Has the Most Developed Solar Compliance Framework in the Region
The UAE’s four emirate-level utilities each operate formal solar programs with published tariffs, approved equipment lists, and digital application portals. SurgePV has published seven dedicated guides covering every UAE emirate — from DEWA Shams Dubai to EtihadWE’s Northern Emirates DSS program. Visit the UAE solar compliance hub for the full emirate-by-emirate breakdown.
Regional Market Overview 2026
The Middle East solar market is no longer a frontier market — it is a mature procurement environment with GW-scale tenders, sub-2-cent LCOE records, and increasingly sophisticated distributed generation regulations. The compliance gap between countries is narrowing, but significant differences remain in net metering/net billing rules, system size caps, contractor accreditation requirements, and equipment standards.
| Country | Installed Solar (End 2025) | Target (2030) | Net Metering / Export Scheme | Max System Size (Distributed) |
|---|---|---|---|---|
| UAE | ~6.7 GW | 19.8 GW clean energy | Net metering at consumer tariff slab (DEWA) / kWh offset (ADDC) | 1 MW (DEWA) / 5 MW (ADDC) |
| Saudi Arabia | ~12 GW | 40–70 GW solar | Cash payment 0.07 SAR/kWh (residential) | 2 MW per premises |
| Jordan | ~2.1 GW | 31% renewable share | Net billing (Bylaw 58, 2024) | 5.4 kWp residential / no cap for C&I since Sept 2024 |
| Egypt | ~3.2 GW | 42% renewable share | kWh offset / cash payment via EETC | 25 MW per project / 30 MW per customer |
| Oman | ~1.6 GW | 13.5 GW by 2040 | Feed-in tariff (Sahim scheme) | ~10 kW typical residential |
| Israel | ~4.0 GW | 30% renewable by 2030 | Net metering (pre-Dec 2025 installs) / mandatory on new builds | 5 kW residential minimum (new builds) |
| Qatar | ~1.7 GW | 4.75 GW by 2030 | Utility-scale only — no retail net metering program | N/A |
| Kuwait | ~50 MW | 2.9 GW by 2030 | No retail net metering programme | N/A |
Use Country-Specific Yield Benchmarks
Solar irradiance across the Middle East ranges from 5.0–6.5 kWh/m²/day depending on location and season. Jordan’s Bylaw 58 of 2024 fixed the annual specific production assumption at 1,800 kWh/kWp/year for compliance calculations. Saudi Arabia’s Najd region exceeds 2,200 kWh/kWp/year in peak areas. Use a solar design software that applies country-level TMY datasets rather than generic Mediterranean irradiance figures — the difference can be 15–20% in annual yield projections.
UAE: The Region’s Most Advanced Solar Compliance Framework
The UAE had approximately 6.7 GW of installed solar by end of 2025, with roughly 1 GW installed in that year alone. The Mohammed bin Rashid Al Maktoum Solar Park in Dubai reached 3.86 GW of operational capacity in 2025, with a 7.26 GW target by 2030. At the distributed level, DEWA reported 725 MW of rooftop solar across 8,430 buildings in Dubai — the largest grid-connected rooftop portfolio in the Middle East.
What distinguishes the UAE is the coexistence of four distinct emirate-level utility programs under a shared Federal Decree-Law No. 17 of 2022 framework. Each utility sets its own application process, approved equipment list, system size limits, and export compensation rules. A solar project in Dubai follows DEWA’s Shams Dubai pathway; the same project 30 kilometres away in Abu Dhabi follows ADDC’s energy netting regulation.
| Emirate | Utility | Program | Max System | Export Compensation |
|---|---|---|---|---|
| Dubai | DEWA | Shams Dubai (v4, June 2022) | 1 MW per plot | Consumer’s own tariff slab (credits never expire) |
| Abu Dhabi / Al Ain | ADDC / AADC | Small-Scale Solar PV Energy Netting | 5 MW per premises | kWh offset — no cash, no expiry |
| Sharjah | SEWA | No formal programme (pilot only) | TBC | TBC |
| Ajman, UAQ, RAK, Fujairah | EtihadWE | DSS (launched Sept 2024) | Programme cap 20 MW aggregate | Calendar-year kWh credits |
The DEWA Shams Dubai process runs through the Hab Reeh digital platform: NOC application → design approval → installation by DEWA-certified contractor (Category A/B/C by system size) → DEWA inspection → bidirectional smart meter installation. All equipment must appear on DEWA’s approved equipment list and carry ECAS (Emirates Conformity Assessment Scheme) certification.
Abu Dhabi adds an RSB (Regulation and Supervision Bureau) approval step before the ADDC/AADC connection application. EtihadWE’s DSS launched in September 2024 with a 20 MW aggregate cap for the northern emirates — check current availability before designing for RAK, Ajman, Umm Al Quwain, or Fujairah.
Seven Dedicated UAE Compliance Guides
SurgePV has published detailed emirate-by-emirate guides covering the full Shams Dubai application workflow, ADDC energy netting, EtihadWE DSS, SEWA Sharjah status, UAE C&I solar considerations, and a UAE solar design software comparison. Visit the UAE solar compliance hub for the complete series, or go directly to the DEWA Shams Dubai guide for the full Hab Reeh application walkthrough.
Saudi Arabia: Vision 2030 and the SEC Net Metering Framework
Saudi Arabia is the Middle East’s largest solar market by installed capacity. The country reached approximately 12 GW of installed solar by end of 2025 — up from near-zero in 2020 — making it one of the fastest solar buildouts ever recorded. Vision 2030 originally targeted 40 GW of solar by 2030; more recent projections from Rystad Energy put the trajectory toward 70 GW by 2030, driven by a sustained pipeline of utility-scale IPP tenders.
Vision 2030 Renewable Energy Programme
Saudi Arabia’s National Renewable Energy Programme (NREP) targets 58.7 GW of total renewable capacity by 2030, with solar as the dominant source. The programme is managed by the Saudi Power Procurement Company (SPPC) through competitive IPP tenders. Key milestones:
- Al Shuaibah Solar IPP (2.6 GW): Commissioned 2024–2025 in phases — one of the world’s largest single-site solar plants
- Sudair Solar Farm (1.5 GW): Operational 2023
- NEOM Oxagon and Sindalah: Solar-plus-storage components under the NEOM giga-project; NEOM targets 100% renewable energy for the city-development
- 2025–2028 tender pipeline: 15 GW of renewable capacity planned including 12 GW solar
SEC Net Metering Rules (In Force Since July 2018)
Saudi Arabia’s distributed solar framework is governed by the Regulatory Framework for Renewable Energy Generation Units of the Customers issued by ECRA (Electricity and Cogeneration Regulatory Authority — now integrated into SERA). Key rules:
| Parameter | Saudi Arabia Rule |
|---|---|
| Effective date | July 1, 2018 |
| Maximum system size | 2 MW per premises |
| Aggregate area cap | 5 MW per distribution department area |
| Residential export rate | 0.07 SAR/kWh (~USD 0.019/kWh) |
| Commercial/industrial export rate | 0.05 SAR/kWh (~USD 0.013/kWh) |
| Settlement period | Annual — after one year of operation, net exported kWh are compensated in cash |
| Metering | Two bidirectional meters — first paid by DSP, second paid by consumer |
| Connection voltage | Distribution system (low voltage) |
The annual settlement mechanism is a key difference from UAE’s rolling credit system: Saudi prosumers accumulate export credits throughout the year and receive a cash payment annually at the regulated tariff rate. The commercial rate of 0.05 SAR/kWh is low relative to the cost of grid electricity (approximately 0.18–0.20 SAR/kWh for commercial customers), which means the economic optimum for C&I systems is to maximise self-consumption rather than export.
Saudi Arabia C&I Solar and SETCO Requirements
Large C&I solar projects in Saudi Arabia — particularly those above 2 MW or seeking project finance — typically engage with the Saudi Energy Efficiency Center (SEEC, previously SETCO) for energy efficiency compliance alongside the SEC net metering application. For utility-scale projects, the SPPC procurement framework and a Power Purchase Agreement (PPA) with SEC replace the net metering pathway entirely.
NEOM and the Green Hydrogen Opportunity
NEOM’s renewable energy programme — anchored by the NEOM Green Hydrogen Company (NGHC) joint venture between ACWA Power, Air Products, and NEOM — is building 4 GW of solar and 4 GW of wind to power 2.2 GW of electrolysis capacity. NEOM represents the most ambitious renewables-to-hydrogen project in the Middle East and serves as a template for future Saudi industrial-scale renewable development. Solar installers and solar software vendors targeting the Saudi market should build familiarity with the SPPC procurement framework — it will govern the next 50+ GW of capacity.
Jordan: Leading Arab Solar Market, Transition to Net Billing
Jordan punches well above its weight in solar deployment. The country had 2,073 MW of on-grid solar PV installed by end of 2024 — an extraordinary figure for a country with a population under 11 million. Solar accounts for a growing share of Jordan’s generation mix as the country imports approximately 85–90% of its energy needs and has prioritised solar to reduce fuel import dependency.
Jordan’s Renewable Energy and Energy Efficiency Law (originally No. 13 of 2012, updated to Law No. 12 of 2024) established the legal foundation for distributed solar. The country has consistently been among the most progressive Arab solar markets in regulatory development.
The 2024 Transition: From Net Metering to Net Billing
Bylaw 58 of 2024 — issued under the updated Renewable Energy and Energy Efficiency Law No. 12 of 2024 — replaced the old net metering framework and introduced four on-grid connection mechanisms effective September 2024:
| Mechanism | Description | Who It Suits |
|---|---|---|
| Net Billing | Excess monthly daytime generation purchased by distribution company at regulated rate | Most residential and SME users |
| Self-Consumption with Export | System prioritises own consumption; surplus exported at regulated rate | Commercial sites with high daytime load |
| Buy-All / Sell-All | All generation sold to utility; consumer buys all consumption separately | Larger C&I and independent producers |
| Off-Grid | No grid connection — full self-supply | Remote sites and backup power |
Key technical parameters under Bylaw 58:
- Annual specific electricity production fixed at 1,800 kWh/kWp/year for compliance calculations
- DC:AC ratio fixed at 1.5 for residential systems, 1.2 for other sectors
- Residential single-phase meter cap: 5.4 kWp
- Residential three-phase meter cap: 15 kWp
- No capacity cap for C&I systems since the 1 MW AC limit was lifted in September 2024
Grid Fee: Bylaw 58 introduced a “Grid Fee” charged to all connection mechanisms except Buy-All/Sell-All. The commercial sector grid fee is 13 JD (~USD 18.3) per kWac/month. This grid fee reduces the economic return on C&I systems that export to the grid — sizing systems for self-consumption optimisation is more important than under the old net metering framework.
Distribution Utilities in Jordan
Jordan’s grid is divided among three distribution companies:
- JEPCO (Jordan Electric Power Company): Amman and the central region — the largest DSO, covering most of the population
- IDECO (Irbid District Electricity Company): Northern Jordan including Irbid, Ajloun, and Jerash
- EDCO (Electricity Distribution Company): Southern Jordan including Aqaba, Ma’an, Karak, and the Jordan Valley
Applications for distributed solar are filed with the relevant distribution company. NEPCO (National Electric Power Company) manages the transmission system and wholesale market; retail distributed generation does not connect at transmission level.
Time-of-Use (ToU) tariffs were expanded to twelve sectors in January 2025 and are expected to cover all sectors by end of 2025. ToU introduces off-peak periods aligned with peak solar generation (5 AM–5 PM), which affects the economics of self-consumption sizing — a solar design software that models ToU dispatch against Jordan’s published tariff tiers will produce more accurate payback projections than simple flat-rate models.
Jordan’s 1 MW Cap Is Gone
The 1 MWAC system size cap that Jordan imposed in 2019 was lifted in September 2024 alongside Bylaw 58. C&I and industrial projects in Jordan can now be designed without this constraint. Large-scale rooftop and ground-mount solar for industrial facilities and commercial parks is now viable under the new Buy-All/Sell-All mechanism for projects exceeding the self-consumption threshold.
Egypt: EgyptERA Net Metering Scheme and the 1,000 MW National Cap
Egypt had approximately 3.2 GW of operational solar by end of 2025, with an ambitious pipeline targeting 3 GW of additional solar and 600 MW of battery storage planned for commissioning in 2026. Total renewable capacity reached 9.1 GW in 2025, with solar overtaking wind as the country’s largest renewable source.
Net Metering Regulatory Framework
Egypt’s net metering scheme is governed by EgyptERA (Egyptian Electric Utility and Consumer Protection Regulatory Agency) and administered through the EETC (Egyptian Electricity Transmission Company) for high-voltage connections or local distribution companies for low-voltage connections.
The scheme has evolved through several regulatory updates since its establishment. Key parameters as of 2026:
| Parameter | Egypt Rule |
|---|---|
| National aggregate cap | 1,000 MW across all net metering projects |
| Max size per project | 25 MW (increased from 20 MW in 2022) |
| Max total per customer | 30 MW across all projects (increased from 25 MW) |
| Exemption from Merger Fee | Projects up to 10 MW capacity |
| Connection authority (LV) | Local distribution company |
| Connection authority (MV/HV) | EETC |
| Licensing | EgyptERA licence required |
The national 1,000 MW aggregate cap is the most significant constraint for the Egyptian market. Once the cumulative net metering capacity registered nationwide reaches 1,000 MW, no new net metering projects can be approved until the cap is revised. Egypt’s track record of incrementally raising the cap (originally 300 MW, raised to 1,000 MW) suggests future upward revisions are likely as demand grows — but timing is uncertain.
Egypt’s Utility-Scale Solar Ambition
Egypt’s solar strategy is primarily focused at utility scale. The Benban Solar Park in Aswan — the world’s fourth-largest solar park at 1,650 MW — was developed under the feed-in tariff (FiT) programme. The next phase of Egypt’s renewable buildout is driven by:
- Independent Power Producers (IPPs) under EETC’s competitive tender framework
- Government-owned NREA (New and Renewable Energy Authority) utility-scale projects
- Green hydrogen projects in the Suez Canal Economic Zone
For C&I buyers in Egypt, the net metering scheme remains the primary distributed generation pathway. The 25 MW per-project cap accommodates large industrial facilities. Industrial zones around Cairo, Alexandria, and Suez — with high electricity consumption and flat roof areas — represent the core distributed solar market.
Egypt Net Metering Application Process
Egypt’s net metering application involves two authorities: EgyptERA issues the required licence for the solar generation facility, and the distribution company (or EETC for HV connections) processes the grid connection application. Both must be completed before installation. The process typically takes 3–6 months for mid-size C&I projects. Engage a local licensed electrical consultant at project initiation — EgyptERA requires specific documentation formats and certified drawings.
Design Middle East Solar Systems Faster with Country-Specific Tools
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Other Middle East Markets
Oman: Sahim Feed-in Tariff Scheme
Oman reached 1.6 GW of installed solar by end of 2025 — making it the fifth GW-scale solar market in the region. The country’s utility-scale buildout has been rapid: the Ibri II Solar IPP (500 MW) and Amin Solar PV project (300 MW) came online in 2022–2024, and the 500 MW Mis Solar IPP is planned for 2027 commissioning.
For distributed solar, Oman operates the Sahim scheme administered by the Authority for Public Services Regulation (APSR). Unlike UAE and Jordan which use net metering, Oman’s Sahim uses a feed-in tariff:
- Sahim I: Customers install grid-connected PV at their own cost and receive a feed-in tariff at the bulk supply tariff rate for all exported electricity
- Sahim II: Third-party solar developers install, own, and operate rooftop systems on customer premises under long-term arrangements — targeting 250,000 residential rooftop installations (approximately 1 GW) by 2025–2030
- Small and medium PV capacity reached 130 MW by late 2025
Oman’s long-term solar target is 13.5 GW by 2040. The APSR maintains the regulatory framework; check the APSR Sahim page for current tariff rates and enrollment status.
Israel: Mandatory Rooftop Solar from December 2025
Israel had approximately 4 GW of installed solar by end of 2025, with the Israel Electric Corporation (IEC) operating the grid and administering net metering for eligible systems.
Two significant developments in 2025–2026:
1. Mandatory solar on new buildings (December 11, 2025): A new regulation requiring all new residential and certain non-residential buildings to install rooftop solar panels to obtain construction permits. Requirements:
- New detached residential buildings with roofs larger than 100 m²: minimum 5 kW PV
- New non-residential buildings with rooftop areas above 250 m²: capacity (kW) = roof area (m²) ÷ 20, capped at 15 kW
- Expected to add 3.5 GW of solar capacity by 2040
2. Two-tariff net metering reform (March 2025): The Israeli Electricity Authority proposed splitting net metering into two separate tariffs — a higher rate for self-consumption hours and a lower rate for grid export. This represents a move toward time-differentiated compensation, similar to the direction taken by California (NEM 3.0) and parts of Europe. New net metering enrollment for systems not already connected was paused pending the tariff reform outcome; check current IEC rules before designing new Israeli systems.
Qatar: Utility-Scale Focus, No Retail Net Metering
Qatar added 875 MW of solar in early 2025 (the Mesaieed and Ras Laffan complexes), raising national capacity to approximately 1.7 GW. The Al Kharsaah Solar IPP (800 MW, operational October 2022) was developed as a joint venture involving QatarEnergy and QEWC (Qatar General Electricity and Water Corporation).
Qatar’s solar programme is currently utility-scale only:
- No formal retail net metering programme exists for residential or commercial customers
- QEWC’s BeSolar programme has been announced but details remain limited as of April 2026
- The planned 2,000 MW Dukhan solar project (Samsung C&T construction contract) aims for 1,000 MW by 2028 and full completion by 2029
- Qatar’s renewable capacity is projected to reach 4.75 GW by 2030 (13.2% CAGR)
For solar contractors and C&I buyers in Qatar, the current route to rooftop solar is through direct engagement with QEWC or Kahramaa (Qatar General Electricity and Water Corporation) — there is no standardised public-facing net metering application framework comparable to UAE or Jordan.
Kuwait: Nascent Market with GW-Scale Ambitions
Kuwait had approximately 50 MW of installed PV by end of 2024 — the smallest installed base of any major Gulf state. Kuwait’s electricity demand has historically been met almost entirely by oil and gas generation, and the solar buildout is at an early stage.
Key developments:
- 500 MW Al Dibdibah and Shagaya Phase III tender: Kuwait Authority for Partnership Projects (KAPP) has opened competitive bidding; construction expected 2026–2028
- Ministry of Electricity and Water (MEW) three-year roadmap: Announced January 2026, targets significant renewable capacity additions through a structured procurement programme
- 2030 target: Rystad Energy forecasts 2.9 GW of cumulative solar by 2030; longer-term projections reach 10.1 GW by 2035
- 15% renewable share target by 2035 (revised from the original 2030 target)
There is currently no retail net metering programme in Kuwait. All solar development is utility-scale under KAPP or government procurement. Companies anticipating Kuwait market entry should monitor KAPP tender announcements and MEW policy updates through 2026–2027.
Country Comparison: Middle East Solar Compliance at a Glance
| Country | Framework Maturity | Net Metering / Export | Max Distributed System | Cash Export Payment | Foreign Companies |
|---|---|---|---|---|---|
| UAE (DEWA Dubai) | Very high (2015, 4 versions) | Net metering at consumer tariff slab | 1 MW per plot | No — tariff credit only | Yes (DEWA-approved contractor required) |
| UAE (ADDC Abu Dhabi) | High (2017) | kWh credit offset | 5 MW per premises | No — kWh credit only | Yes |
| Saudi Arabia | Moderate (2018) | Annual cash payment | 2 MW per premises | Yes — 0.07 SAR/kWh residential | Yes (SEC DSP licence required) |
| Jordan | High, evolving (2024 reform) | Net billing at regulated rate | Uncapped for C&I (Sept 2024) | Yes — purchase of net exports | Yes |
| Egypt | Moderate | Net offset + cash via EETC | 25 MW per project | Yes (via EETC) | Yes |
| Oman | Moderate (Sahim FiT) | Feed-in tariff for all exports | ~10 kW typical residential | Yes — FiT rate | Yes |
| Israel | High (mandatory solar from Dec 2025) | Net metering (reform pending) | 5 kW minimum residential | Pending tariff reform | Yes |
| Qatar | Low (utility-scale only) | No retail programme | N/A | N/A | Via QEWC engagement |
| Kuwait | Very low (nascent) | No retail programme | N/A | N/A | Via KAPP tenders |
Common Compliance Issues in the Middle East
Solar projects in the Middle East stall for predictable, avoidable reasons. The issues differ by country but fall into consistent categories across the region.
Using Unapproved Contractors or Equipment
UAE: DEWA, ADDC, and EtihadWE each maintain separate approved contractor and equipment lists. A contractor approved for Dubai projects is not automatically approved for Abu Dhabi — they must appear on the relevant utility’s list. Equipment not on the DEWA approved equipment list cannot be used in Shams Dubai projects, regardless of IEC certification. Check both the contractor list and the equipment list before signing any contract.
Saudi Arabia: Contractors working on SEC net metering systems must hold SEC/SERA licensing. Using an unlicensed contractor voids the net metering application and requires re-submission.
Incorrect System Sizing for Export Optimisation
In markets with low export rates (Saudi Arabia: 0.05–0.07 SAR/kWh; Jordan: grid fee reduces net export value), oversizing for maximum generation is counterproductive. The economic optimum is self-consumption maximisation — size the system to cover annual on-site consumption at or slightly below 100%. A generation and financial tool that models the specific country tariff, export rate, and grid fee structure will produce a more accurate sizing recommendation than a generic payback calculator.
Failing to Account for National Aggregate Caps
Egypt’s 1,000 MW national net metering cap is the most acute example — when the cap fills, new applications stop. Jordan’s 1 MW AC cap (now lifted) affected projects for five years between 2019 and 2024. Saudi Arabia’s 5 MW aggregate cap per distribution area can constrain multi-site C&I portfolios. Verify current cap utilisation before committing to a project timeline in any market with a published aggregate limit.
Connecting to the Grid Without Written Approval
Across every Middle East market covered in this guide, the requirement is the same: do not energise or connect a solar system to the grid without written approval from the competent authority. In the UAE, this means the NOC from DEWA, the PV Connection Agreement from ADDC, or the connection confirmation from EtihadWE. In Saudi Arabia, this is the SEC connection approval. In Jordan, the distribution company connection consent. In Egypt, the EgyptERA licence and EETC connection agreement. Unauthorised connection results in disconnection, financial penalties, and — in some jurisdictions — refusal of future applications by the same contractor.
Using Generic Irradiance Data
The Middle East has some of the highest DNI and GHI values globally, but there is significant intra-region variation. Saudi Arabia’s Rub’ al Khali (Empty Quarter) regularly exceeds 6.5 kWh/m²/day; coastal Oman and parts of Jordan can be 15–20% lower due to humidity and dust. Jordan’s Bylaw 58 of 2024 fixed the compliance calculation at 1,800 kWh/kWp/year — a site-specific yield above this figure does not entitle the owner to a larger system under the residential cap. Use satellite-derived TMY data specific to the project location, not regional averages.
Frequently Asked Questions
Which Middle East country has the most developed solar net metering framework?
The UAE leads the region with four emirate-level utility programs, the longest track record (Shams Dubai since 2015), the largest approved equipment and contractor lists, and digital application portals. The UAE solar compliance hub at /solar-compliance/uae/ covers all seven emirates in detail.
What are Saudi Arabia’s solar targets under Vision 2030?
Saudi Arabia’s Vision 2030 programme targets 58.7 GW of total renewable capacity by 2030, with solar accounting for 40 GW. Rystad Energy projects the country could reach 70 GW of solar by 2030 at current build rates. As of end 2025, approximately 12 GW was installed. The SEC net metering programme allows systems up to 2 MW and pays 0.07 SAR/kWh to residential prosumers annually.
How does Jordan’s net billing work?
Bylaw 58 of 2024 replaced net metering with four connection mechanisms effective September 2024. The primary option for most users is net billing, where excess monthly daytime generation is purchased by the distribution company at a regulated rate. Residential systems are capped at 5.4 kWp (single-phase) or 15 kWp (three-phase). The 1 MW AC cap on larger systems was removed in September 2024. A grid fee applies to most mechanisms for commercial users.
Can foreign companies install solar in the UAE?
Yes. Foreign-owned companies and foreign nationals can access all UAE solar programs. The requirement is to use a DEWA-approved contractor (for Dubai), ADDC-approved consultant and integrator (for Abu Dhabi), or EtihadWE-approved contractor (for Northern Emirates). Foreign contractors can apply for utility accreditation directly. The nationality of the building owner or tenant does not restrict program access.
What is the status of Egypt’s solar net metering scheme?
Egypt’s scheme allows projects up to 25 MW per installation and 30 MW total per customer, with a 1,000 MW national aggregate cap. EgyptERA licenses the solar generation facility; the EETC or local distribution company handles the grid connection agreement. Egypt had approximately 3.2 GW of operational solar by end of 2025, with 3 GW of additional solar planned for 2026 commissioning — all utility-scale.
