UAE Solar Compliance Guide 2026: DEWA, SEWA, and Emirate-Specific Requirements

Solar compliance in the UAE is not one rulebook — it is 7. Each emirate runs its own utility, its own approval workflow, and its own grid-connection standards. A design that clears DEWA review in Dubai can fail SEWA review in Sharjah for reasons that have nothing to do with engineering quality. We see EPCs lose 4–6 weeks per project to this fragmentation, usually on paperwork rather than hardware.

This guide covers solar compliance in the UAE across DEWA, SEWA, and the other emirate utilities. It is written for EPCs, installers, and developers who need a single reference for approval workflows, equipment standards, and net metering rules. Where a rule varies by emirate, we flag it explicitly.

In this guide:

• The 2026 policy changes affecting UAE distributed solar
• How DEWA Shams Dubai works, step by step, with real timelines
• SEWA requirements for Sharjah and how they differ from DEWA
• Abu Dhabi, the northern emirates, and the federal framework
• Net metering mechanics, credit rates, and settlement rules by emirate
• Equipment standards, approved product lists, and certification requirements
• The full approval workflow from NOC to commissioning
• The compliance mistakes that delay UAE projects — and how to avoid them

Latest Updates: UAE Solar Policy 2026

UAE solar policy keeps moving, and 2026 brought changes that affect how EPCs scope and price projects. Here is what matters for compliance planning this year.

First, DEWA has continued tightening its contractor registration requirements. Only consultants and contractors enrolled in DEWA’s Shams Dubai registry can submit applications. The registry now requires renewed documentation annually, and lapses block application submission. EPCs working across Dubai and Sharjah need separate enrollments — DEWA registration does not transfer to SEWA.

Second, net metering credit rules remain emirate-specific. Dubai credits exported energy against consumption at the applicable tariff rate, settled monthly against the bill. Other emirates apply their own settlement periods and credit mechanics. There is still no unified federal net metering framework, despite periodic discussion at the Ministry of Energy and Infrastructure level. Design your financial models per emirate, not per country.

Third, equipment lists keep updating. DEWA’s approved module and inverter lists are revised several times per year. An inverter approved in January can be delisted by September if certification lapses. We recommend re-checking the list at proposal stage and again at procurement — a delisted model found at inspection means replacement at your cost.

Fourth, utility-scale and distributed solar targets continue to pull grid capacity. The UAE Energy Strategy 2050 targets 44% clean energy in the generation mix, and Dubai’s Clean Energy Strategy 2050 targets 100% clean capacity by 2050. For distributed installers, the practical effect is continued utility support for rooftop solar — but also growing scrutiny of grid-impact studies on larger commercial systems.

The table below summarizes the 2026 state of play by emirate.

The direction of travel is clear: more rooftop solar, more structured approvals, and less tolerance for incomplete submissions. EPCs that standardize their compliance documentation per emirate win weeks on every project.

One more 2026 development deserves attention from commercial installers. Industrial and logistics customers across Dubai, Sharjah, and Abu Dhabi are procuring rooftop solar at a pace the distribution networks were not built for. Utilities are responding with more frequent export-capacity questions at design review, even on mid-size systems. Projects that model expected export against the connection capacity early — and show that work in the submission — clear review faster than projects that leave the question open. We expect export screening to become a formal step in more emirate frameworks over the next 2–3 years.

The UAE Solar Regulatory Framework

The UAE is a federation of 7 emirates, and electricity regulation sits primarily at the emirate level. This is the single most important fact for solar compliance in the UAE. There is no equivalent of a national permitting authority for rooftop solar.

Each emirate has its own utility or utilities. Dubai has the Dubai Electricity and Water Authority (DEWA). Sharjah has the Sharjah Electricity, Water and Gas Authority (SEWA). Abu Dhabi is served by 2 distribution companies — Abu Dhabi Distribution Company (ADDC) for the city and Al Ain Distribution Company (AADC) for the eastern region — both regulated by the Abu Dhabi Department of Energy. The northern emirates (Ajman, Ras Al Khaimah, Fujairah, Umm Al Quwain) are served by Etihad Water and Electricity (EtihadWE), successor to the Federal Electricity and Water Authority.

Oversight above the utilities splits 2 ways. The federal Ministry of Energy and Infrastructure sets national energy strategy. Emirate-level regulators — most notably Dubai’s Supreme Council of Energy and Abu Dhabi’s Department of Energy — set the rules that utilities implement. For a rooftop solar project, the utility is your day-to-day counterparty.

The practical consequence is that compliance work multiplies by emirate. Application forms differ. Required drawings differ. Approved equipment lists differ. Even the definition of terms like net metering varies in settlement detail. An EPC working in Dubai and Sharjah maintains 2 compliance playbooks, not 1.

Here is how the utilities compare on the dimensions that matter most to installers.

One pattern holds across all 7 emirates: the utility owns the grid connection, and nothing energizes without its written approval. No utility in the UAE treats rooftop solar as a self-declared, install-then-notify activity. Every project is an application, a review, an inspection, and a connection agreement.

For EPCs expanding into the UAE, the sequencing decision is which emirate to enter first. Dubai is the most process-mature and the highest volume. Sharjah is adjacent, growing, and slightly slower. Abu Dhabi is lucrative for commercial work but demands stronger grid-study capability on larger systems. The northern emirates reward patience and local partnership.

We recommend building your documentation templates around the strictest requirements you face — usually DEWA’s — and then trimming per emirate. Over-documenting for SEWA costs you nothing. Under-documenting for DEWA costs you a review cycle.

DEWA Shams Dubai: Dubai’s Solar Program

Shams Dubai is DEWA’s distributed renewable energy program, launched in 2015 and now the reference implementation for rooftop solar in the region. It allows residential, commercial, and industrial customers to install PV systems, connect to the DEWA grid, and receive net metering credits for exported energy. Full program details live on the DEWA Shams Dubai page.

The program’s defining feature is structure. Every step is documented, portal-based, and tracked. For installers used to less formal markets, the discipline is a feature — timelines are predictable once your documentation standard matches DEWA’s expectations.

Who Can Apply

Applications must be submitted by DEWA-enrolled contractors or consultants. Enrollment requires trade license documentation, engineering qualifications, and insurance. The customer signs authorization, but the enrolled contractor drives the process. Individual homeowners cannot self-install and connect — this is not a DIY jurisdiction.

Residential systems are typically capped around 10 kW. Commercial and industrial systems scale much larger but trigger deeper grid-impact review. The cap that applies to your project depends on the connection type and the premise’s sanctioned load, not just the roof size.

The Shams Dubai Approval Sequence

1. NOC application. The contractor submits a No Objection Certificate request through the DEWA portal with customer details, premise information, and the proposed system summary.
2. Design submission. Full design package follows: single-line diagram, module and inverter datasheets from the approved lists, structural drawings, and layout plans.
3. Design review. DEWA engineers review the package. Comments come back through the portal. Clean first-pass packages typically clear in 2–3 weeks.
4. Installation. Work proceeds only after design approval. Deviating from the approved design without a revision triggers inspection failure.
5. Inspection request. The contractor requests a site inspection after installation is complete and documented.
6. Inspection and connection approval. DEWA inspects the installation against the approved design. Passing grants permission to connect.
7. Metering and commissioning. DEWA installs or configures the bidirectional meter and the system energizes under the net metering agreement.

Timelines We Actually See

DEWA quotes structured service-level targets, and end-to-end approvals typically land at 4–8 weeks for standard residential and small commercial work. The distribution inside that range matters. Clean applications with complete drawings clear in 4–5 weeks. Applications with design comments, resubmissions, or inspection scheduling friction run 8 weeks or more. Larger commercial systems with grid studies can run 3–6 months total.

2 factors explain most of the variance. The first is comment cycles — each design-comment round adds 1–3 weeks, and applications with 2 comment rounds routinely double the timeline of clean submissions. The second is inspection scheduling, which tightens during peak installation seasons and around public holidays. EPCs quoting fixed customer deadlines should hold a 2-week buffer on top of the utility’s published targets.

What DEWA Reviews Hardest

In our experience supporting UAE installers, 3 elements draw the most review scrutiny. The single-line diagram must match the approved equipment exactly — model numbers, ratings, and protection devices. The structural drawings must carry a licensed engineer’s stamp and address roof loading, wind loads, and waterproofing penetration details. The earthing and protection scheme must follow DEWA’s connection standards, not generic IEC practice.

Shams Dubai’s discipline extends to metering. Exported energy is measured by the bidirectional meter and credited against consumption at the applicable tariff. Settlement runs monthly against the electricity bill. Credits offset the energy component; fixed charges and other fees remain payable. For customer-facing economics, we model this in the generation and financial tool before the proposal goes out — the difference between monthly and annual settlement assumptions changes projected savings by 5–10% on typical Dubai villas.

One operational note: DEWA’s portal is the single source of truth for application status. Phone follow-ups do not accelerate reviews. Complete submissions accelerate reviews. EPCs that treat the portal checklist as the definition of done consistently beat the 8-week mark.

SEWA and Sharjah Solar Requirements

Sharjah runs its distributed solar program through the Sharjah Electricity, Water and Gas Authority (SEWA). The program’s shape mirrors Dubai’s — application, design review, inspection, net metering — but the details differ enough to break assumptions carried over from DEWA work. Program information is available through SEWA’s website.

We maintain a dedicated walkthrough of the Sharjah process in our SEWA solar guide. This section covers the strategic differences rather than repeating that step-by-step detail.

Where SEWA Matches DEWA

Both utilities require contractor registration before any application. Both require a NOC-equivalent approval before installation. Both mandate equipment from approved product lists, and both inspect before connection. Both settle exported energy as credits against consumption rather than cash payments.

If your documentation standard clears DEWA, the engineering content will clear SEWA. The differences sit in process, forms, and timelines.

Where SEWA Differs

The differences that catch Dubai-first EPCs are practical. Application forms and portal workflows are SEWA-specific — DEWA enrollment carries no weight in Sharjah, and you register separately. System size caps and connection rules follow SEWA’s own framework, which varies by customer category and sanctioned load. Review timelines run longer in our experience: 6–12 weeks end-to-end is a realistic planning number, versus DEWA’s 4–8.

Sharjah also serves a different building stock. The emirate has a large base of older villas, industrial sheds in Sharjah Industrial Area, and mid-rise commercial buildings. Structural documentation gets real attention on older roofs. We have seen SEWA reviewers request structural reassessment on buildings where Dubai’s reviewers would accept standard calculations.

Net Metering Terms in Sharjah

SEWA credits exported solar energy against the customer’s consumption under utility-set terms. The credit rate and settlement mechanics differ from Dubai’s monthly bill-credit model. For customer economics, model Sharjah projects with SEWA’s actual settlement terms — copying a Dubai savings model into a Sharjah proposal overstates or understates returns depending on the customer’s consumption profile.

Planning Guidance for Sharjah

Budget the longer timeline into your customer commitments. A Sharjah residential project quoted at Dubai speed creates an expectation problem at week 5. Sequence procurement after design approval, as with DEWA, and confirm every equipment model against SEWA’s current approved list at order time.

For EPCs choosing between Dubai-first or Sharjah-first market entry: Dubai first. The process is more documented, timelines are shorter, and the installed base is larger. Bring Sharjah online as your second emirate once your compliance documentation is modular enough to fork cleanly.

Other Emirates: ADDC, AADC, and Federal Rules

Beyond Dubai and Sharjah, the compliance picture splits into Abu Dhabi and the northern emirates. The 2 markets behave very differently.

Abu Dhabi: ADDC and AADC

Abu Dhabi’s distribution is handled by 2 companies under the emirate’s energy regulatory framework. Abu Dhabi Distribution Company (ADDC) serves Abu Dhabi city and the western region. Al Ain Distribution Company (AADC) serves the Al Ain region. Both operate under rules set by the Abu Dhabi Department of Energy, which has published a distributed generation framework covering small-scale solar connections. Details are available through ADDC and the Abu Dhabi Department of Energy.

Abu Dhabi’s framework is the most engineering-intensive of the emirate regimes. Connection applications face capacity screening against the local network. Larger commercial systems can trigger grid-impact studies, and the emirate’s transmission-constrained areas see tighter export limits. For commercial and industrial developers, this is the emirate where early utility engagement pays the highest return — a pre-application conversation about network capacity saves months versus discovering a constraint at design review.

Registration requirements mirror the Dubai pattern: approved contractors and consultants submit on behalf of customers. Timelines for standard systems run 6–10 weeks in our experience, with grid-studied commercial systems extending well beyond that.

The Northern Emirates: EtihadWE

Ajman, Ras Al Khaimah, Fujairah, and Umm Al Quwain are served by Etihad Water and Electricity (EtihadWE), which absorbed the former Federal Electricity and Water Authority. Distributed solar frameworks here are less mature. Applications are processed, but with more case-by-case handling and less published structure than DEWA or ADDC provide.

The practical planning numbers: expect 8–12+ weeks, expect requests for supplementary documentation mid-review, and expect less portal transparency. The northern emirates reward EPCs with local presence and patient project management. Ras Al Khaimah, in particular, has active industrial and tourism development that is pulling commercial solar demand ahead of the utility’s published frameworks.

The Federal Layer

The federal Ministry of Energy and Infrastructure sets strategy — most visibly the UAE Energy Strategy 2050 — but does not issue rooftop solar permits. There is periodic discussion of harmonized federal net metering rules. As of mid-2026, no unified federal framework has replaced the emirate-level regimes. Plan your compliance work per emirate, and treat harmonization as a welcome surprise rather than a roadmap assumption.

The strategic takeaway: the UAE is not 1 market of 10 million people. It is 4 distinct compliance markets sharing a border. EPCs that internalize this win multi-emirate work. EPCs that do not keep re-learning it at their customers’ expense.

Net Metering and Grid Connection in the UAE

Net metering is the mechanism that makes UAE rooftop solar economics work. Exported energy offsets imported energy, and the customer pays for the net difference. Our net metering glossary entry covers the general mechanics; this section covers the UAE-specific implementation.

How UAE Net Metering Works

Every emirate’s program shares the same skeleton. The utility installs a bidirectional meter that records energy in both directions. Solar generation serves on-site load first. Surplus exports to the grid and accrues as credits. The customer draws from the grid when solar under-produces, and credits offset those imports at settlement.

The differences sit in 3 variables: the credit rate, the settlement period, and the treatment of excess credits. Dubai credits exports against consumption at the applicable tariff and settles monthly against the bill. SEWA applies its own credit terms. Abu Dhabi’s framework sets regulated credit mechanics through the distribution companies. The northern emirates handle settlement case-by-case.

No UAE emirate currently pays cash for exported residential solar at rates above the retail tariff. The economic case everywhere in the UAE rests on self-consumption first and export credits second. This shapes design: the right system size matches the customer’s daytime load profile, not the maximum the roof or the cap allows.

The Design Implication Nobody Prices Correctly

Here is the tradeoff most UAE proposals get wrong. Installers routinely design to the maximum allowed size — the 10 kW residential cap in Dubai, or the largest commercial array the roof holds. The sales logic is obvious: bigger system, bigger ticket, bigger headline savings number. The grid math disagrees.

A villa with modest daytime occupancy exports heavily at midday. Those exports earn credits worth the energy component of the tariff, but a maximally sized system on a low-daytime-load home can push 40–60% of generation into export. Self-consumed energy is worth the full retail rate avoided. Exported energy is worth the credit rate. On typical UAE residential tariffs, sizing to the customer’s actual load profile rather than the cap improves project economics per installed kW — even though total savings in absolute dirhams look smaller in the proposal.

Grid Connection Technical Requirements

Across all emirates, grid connection requires protection and power-quality compliance at the point of common coupling. Inverters must meet the utility’s grid-code requirements — anti-islanding protection, voltage and frequency ride-through windows, and power factor capability. The single-line diagram submitted at design review must show the protection devices, disconnection points, and metering arrangement exactly as built.

Metering is utility-supplied and utility-configured. The bidirectional meter is installed or reprogrammed by the utility at commissioning, after inspection passes. No emirate permits energization before the connection approval and meter work complete. Systems found energized before approval face disconnection and, in Dubai, contractor registration consequences.

For multi-emirate EPCs, the grid-connection layer is where standardization actually works. Protection schemes, earthing arrangements, and meter-panel layouts designed to the strictest utility standard — typically DEWA’s — pass everywhere else with cosmetic changes. Standardize the engineering, localize the paperwork.

Equipment Standards and Approved Products

UAE utilities do not accept generic IEC certification as sufficient. Modules and inverters must appear on the specific utility’s approved product list, and the lists are maintained independently. A module approved by DEWA is not automatically approved by SEWA or ADDC.

What the Approved Lists Cover

DEWA’s Shams Dubai program publishes lists for PV modules and inverters, with underlying requirements built on IEC 61215 and IEC 61730 for modules, and IEC 62109 plus grid-code conformity for inverters. Manufacturers submit test reports and certificates for listing. The lists carry model-level granularity — a manufacturer’s listing covers named model numbers, not the brand. This trips up procurement teams constantly: the 10 kW inverter is approved, the visually identical 12 kW sibling is not.

SEWA and the Abu Dhabi distribution companies maintain their own lists with their own submission processes. Overlap between lists is high but not total. For multi-emirate EPCs, the safe procurement rule is: a model goes on the truck only after it is confirmed on the destination emirate’s current list.

Certification Layers

Beyond the utility lists, 2 certification layers apply. Modules and inverters need valid IEC certificates from accredited labs, and certificates expire — a listing based on an expired certificate can be revoked mid-project. The UAE’s climate adds a practical layer: high ambient temperatures, dust loading, and coastal humidity punish equipment that merely passes lab minimums. Utilities do not test for this, but warranty claims and degradation curves will.

Inverter grid-code settings deserve specific attention. Utilities require country- or emirate-specific grid codes loaded at commissioning — protection windows, power factor behavior, and reconnection delays. An inverter with the wrong grid profile fails inspection even when the hardware is approved. We verify the grid-code setting against the utility requirement in the commissioning checklist, not from the installer’s memory.

Mounting, Cabling, and Balance of System

Approved-product discipline extends beyond modules and inverters in practice. Structural mounting systems face review through the structural drawings — wind-load calculations to UAE conditions, roof-penetration waterproofing details, and material specifications. DC cabling, isolators, and protection devices must match the approved single-line diagram. Inspectors check labels, ratings, and installation practice against the design package.

When designing to these constraints, solar design software that keeps equipment data, electrical calculations, and the layout in 1 project file reduces the mismatch risk between what you designed and what you submitted. We built SurgePV’s design environment around exactly this discipline — the design you simulate is the design you document.

The Approval Workflow: From NOC to Commissioning

The approval workflow follows the same 7-stage skeleton in every emirate. The forms, portals, and timelines differ; the sequence does not. Master the skeleton once, then learn each utility’s paperwork dialect.

1. Pre-application validation. Confirm contractor registration is current in the target emirate. Confirm the customer’s premise details, sanctioned load, and account status. Confirm every equipment model against the current approved list.
2. NOC submission. File the No Objection Certificate application with customer authorization, premise data, and the proposed system summary. The NOC is the utility’s permission to proceed with design development — not permission to build.
3. Design package submission. Submit the complete design: single-line diagram, layout, structural drawings with engineer stamps, equipment datasheets, and protection scheme. Completeness at this stage is the single largest timeline lever you control.
4. Design review and comments. The utility reviews and returns comments or approval. Respond to comments completely and in a single resubmission — partial responses generate partial re-reviews and multiply the timeline.
5. Installation per approved design. Build exactly what was approved. Any deviation — equipment substitution, layout change, protection change — requires a formal revision before the inspector finds it.
6. Inspection. Request inspection after installation completes with as-built documentation ready. The inspector verifies the build against the approved design and the utility’s installation standards.
7. Connection and commissioning. On inspection pass, the utility approves connection, installs or configures the bidirectional meter, and the system energizes under the net metering agreement.

The timeline differences by emirate, restated for planning:

3 disciplines compress these timelines more than any follow-up call. First, submit complete packages — the review clock starts when the reviewer can actually review. Second, run internal design QA against the utility checklist before submission, not after comments arrive. Third, keep as-built documentation running during installation, so the inspection request goes in the day the last clamp torques.

Shadow and layout documentation deserves a note here. Roof layouts with shading from parapets, water tanks, and neighboring structures are common in UAE villas and mid-rise buildings. Reviewers increasingly expect shading to be addressed in the design package. We generate shading studies with solar shadow analysis software and attach the output to the design submission — it answers the reviewer’s question before they ask it.

For the customer-facing side, the approval timeline belongs in the proposal. A solar proposal software workflow that states the approval window, the customer’s responsibilities, and the payment milestones tied to NOC, approval, and commissioning prevents the 2 most common disputes in UAE residential solar: “why is this taking so long” and “when do I pay.” Set the expectation in writing at signature.

Common Compliance Mistakes That Delay UAE Projects

After supporting UAE installers across hundreds of projects, we see the same delay patterns repeat. None are exotic. All are preventable.

1. Submitting Dubai paperwork to Sharjah. Covered above, and worth repeating because it is the most common cross-emirate failure. Fork your templates properly.

2. Incomplete single-line diagrams. The SLD is the review’s centerpiece. Missing protection ratings, missing cable sizes, or generic symbols instead of named models generate comments on every submission. The fix is a utility-specific SLD template with a completeness checklist.

3. Non-approved or delisted equipment. The model was approved at proposal time and delisted before procurement, or the approved sibling had a different rating. Check the list at order time, every time.

4. Structural drawings without engineer stamps. Self-prepared structural sketches fail everywhere in the UAE. The drawings need a licensed engineer’s stamp and UAE-relevant wind and load calculations. This is not the place to save AED 2,000.

5. Designing to the cap instead of the load. The contrarian point from the net metering section, restated as a compliance issue: oversized designs invite extra scrutiny of export capacity at the connection point, and they underperform financially. Right-sized designs approve faster and perform better. The industry’s reflex to maximize system size is a sales habit, not an engineering conclusion.

6. Building before approval. Installation that starts before design approval is complete risks rework at the installer’s cost when comments arrive. Utilities treat unauthorized early installation harshly. The schedule pressure is real; the rework cost is worse.

7. Deviating from the approved design without revision. The swapped inverter, the moved array, the substituted isolator. Inspectors compare the build to the approved package. File the revision; it takes days. Failing the inspection takes weeks.

8. Wrong inverter grid-code settings. Approved hardware with the wrong country profile fails at commissioning. Verify settings against the utility requirement in the commissioning checklist.

The pattern underneath all 8 mistakes: they are process failures, not knowledge failures. Every installer knows equipment must be approved. The failures come from not checking at the right moment, or from 1 team’s Dubai habit leaking into a Sharjah submission. Checklists beat memory. Per-emirate templates beat universal templates. And a single source of truth for design data beats re-keyed drawings — which is the entire premise of our solar software platform and the reason we build compliance-aware workflows for solar installers.

Conclusion

UAE solar compliance rewards the EPCs who respect its structure. The market is not 1 jurisdiction — it is 4 compliance regimes across 7 emirates, each with its own utility, approved lists, forms, and timelines. DEWA’s Shams Dubai is the most mature: plan 4–8 weeks, follow the portal, match the approved design. SEWA runs a parallel process in Sharjah at 6–12 weeks with its own paperwork. Abu Dhabi demands engineering depth through ADDC and AADC. The northern emirates reward patience through EtihadWE.

The economics underneath every emirate point the same way: self-consumption first, export credits second, and systems sized to the load rather than the cap. The approvals themselves are won or lost on documentation — complete SLDs, stamped structural drawings, listed equipment, and builds that match the submitted design.

3 actions for your next UAE project. First, confirm contractor registration and approved equipment lists in the specific emirate before you price the job. Second, build your design package against that utility’s checklist, with shading studies and stamped structural drawings included from the start. Third, put the approval timeline and milestone structure in the customer proposal, in writing.

A final word on where this market is heading. Emirate-level frameworks are converging in structure even as their paperwork stays separate — more portals, more standardized checklists, more structured review. EPCs that invest in compliance systems now will find each new emirate cheaper to enter than the last. EPCs that rely on memory and heroics will find the opposite.

The UAE remains 1 of the strongest distributed solar markets in the region — high irradiance, supportive strategy targets, and utilities that actively process rooftop connections. The installers who systematize compliance per emirate will absorb that growth. The ones who treat the UAE as 1 market will keep donating weeks to avoidable resubmissions.

Frequently Asked Questions

What is Shams Dubai?

Shams Dubai is DEWA’s distributed renewable energy program. It allows residential and commercial customers in Dubai to install solar panels and connect to the grid with net metering. Systems must use approved equipment and follow DEWA guidelines.

How do I get solar approval from DEWA?

Apply through the DEWA portal with a No Objection Certificate (NOC) request. Submit system design, module and inverter datasheets, and structural drawings. DEWA reviews, inspects the site, and grants permission to install and connect.

What is the difference between DEWA and SEWA solar rules?

DEWA covers Dubai with the Shams Dubai program and net metering. SEWA covers Sharjah with similar but separate rules. Each emirate has its own utility, regulations, and approval process.

Is net metering available in the UAE?

Yes, net metering is available in Dubai through Shams Dubai and in other emirates through their respective utilities. Exported energy is credited against consumption, but the credit rate and settlement period vary by emirate.

What size solar system is allowed in the UAE?

Residential systems in Dubai are typically capped at 10 kW. Commercial systems can be larger but need DEWA approval. The exact cap depends on the emirate, utility, and connection type.

How long does UAE solar approval take?

DEWA approval typically takes 4–8 weeks. SEWA and other emirate utilities may take 6–12 weeks. The timeline depends on application completeness, site inspection scheduling, and utility workload.