Energy counsel where the resource is emirate property and the money is federal.

Where the rights sit — and why every other question follows from it

The defining feature of UAE energy law is not a statute. It is an allocation of sovereignty. Under the federal constitutional settlement, natural resources are the property of the emirate in which they are located, and the emirate — not the federation — decides who may explore for them and produce them, and on what terms. There is no national petroleum code, no federal licensing round, and no ministry that can grant an upstream interest.

What the federal level holds is substantial but different in kind: foreign investment and companies law, labour, customs, corporate tax, environment and climate policy, nuclear safety regulation, and the treaty framework governing enforcement. A producing asset in Abu Dhabi is granted under Abu Dhabi arrangements, staffed under federal labour rules, taxed under a mixture of emirate fiscal terms and federal corporate tax, and litigated through an award enforced at federal level.

This is why generic “UAE oil and gas” advice is close to useless. The first question is not what the contract says. It is which emirate the hydrocarbons are in, which instrument grants the right, which body must approve a transfer or change of control, and whether your counterparty holds the right or merely operates under it. Answer those four and most of the structuring follows. Skip them and you spend six months negotiating terms a consent condition will unwind.

Free zones do not change this. DIFC and ADGM are common-law jurisdictions with their own courts, companies laws and arbitration frameworks — genuinely useful for holding vehicles, financing and dispute resolution. They confer no petroleum rights. An ADGM-incorporated company can hold a participating interest; the interest is still granted, regulated and forfeited under Abu Dhabi arrangements.

The Abu Dhabi model: concessions, participating interests, and the national operator

Abu Dhabi holds the overwhelming majority of UAE reserves and sets the tone for the sector. Its architecture is built around ADNOC as national operator and asset-holder, supervised by the emirate’s supreme economic and petroleum governance bodies, with the Abu Dhabi Department of Energy regulating power, water and downstream activity within the emirate.

The commercial model matters to anyone drafting for it. Abu Dhabi has historically favoured concession and participating-interest structures rather than the production sharing contracts familiar from Southeast Asia and West Africa. International partners take a minority interest in a defined block or asset, contribute their share of capital and technical capability, lift their entitlement share, and pay emirate-level royalties and taxes — with the national company holding the majority and, usually, operatorship. Cost recovery mechanics, entitlement volumes, reserve booking and decommissioning provisions all behave differently from a PSC, and a model built on PSC assumptions will misprice the asset.

Two features drive most of the negotiation. The first is consent architecture: assignment, change of control, farm-in and farm-out, and often security over the interest, require approvals whose timing is not within the parties’ control. Conditions precedent should be drafted to that reality, with long-stop dates that reflect it and a clear allocation of delay cost. The second is in-country value. ICV certification and local content scoring are procurement facts, not aspirations: they shape subcontracting, joint venture percentages and manufacturing footprint, and belong in the commercial model from the outset rather than retrofitted when a bid is scored.

Dubai, Sharjah and the northern emirates

Dubai’s own hydrocarbon production is modest and mature, and its energy identity is built elsewhere: trading, storage, refining and distribution, plus one of the region’s most active utility-scale power procurement programmes through DEWA. The Dubai Supreme Council of Energy sets policy at emirate level; DEWA operates as generator, transmission and distribution utility and — critically for developers — as offtaker under Dubai’s IPP programme.

Sharjah has its own long-standing gas position, national oil company and petroleum council, and has awarded exploration and production interests on Sharjah terms. Ras Al Khaimah, Umm Al Quwain and Ajman have each pursued exploration on their own account. Fujairah’s significance is different and often underestimated: as a port on the Gulf of Oman outside the Strait of Hormuz, it anchors storage, bunkering and export infrastructure, and contracts touching it are shaped by maritime, war-risk and sanctions considerations rather than upstream regulation.

The practical instruction is frequently ignored: do not port terms between emirates. Grantor, approval route, fiscal treatment and the identity of the state-linked counterparty all change, and institutional risk appetite changes with them.

Oilfield services: the contracts that actually get negotiated

Most energy legal work in the UAE is not concession work. It is the services and supply layer beneath it — drilling and workover, well services, completions and stimulation, integrated project management, subsea and marine spread, FPSO and FSO arrangements, equipment leasing, EPC and EPCI packages, and long-term frame agreements with the national operators. Four issues consume the negotiation, in roughly this order.

• Liability and indemnity. The default is mutual knock-for-knock: each party bears its own people and property regardless of fault. Efficient and insurable — but under UAE-governed contracts not absolute. The Civil Transactions Law restricts agreements purporting to relieve a party of liability for harmful acts, and its treatment of gross fault and wilful misconduct limits how far a mutual hold-harmless is honoured. Draft to the fault categories the law recognises, and build the insurance programme to match the allocation rather than assuming it follows.
• Consequential loss. A common-law term of art with a body of authority behind it, which UAE onshore courts and UAE-law tribunals do not import automatically. Define the excluded heads expressly — lost production, deferred production, loss of profit, loss of use — rather than relying on the label to do the work.
• Pricing and change. Day rate, lump sum, reimbursable and integrated pricing each allocate a different risk. Disputes rarely concern the headline rate; they concern standby, waiting on weather, downtime attribution, variation valuation and the evidential threshold for a claim. Get the records regime and notice mechanics right and most never mature.
• Compliance and disclosure. State-linked counterparties raise anti-bribery, sanctions, export control and beneficial ownership questions that are not boilerplate. Intermediaries need diligence proportionate to the exposure, and sanctions clauses must work under the laws of every jurisdiction touching the chain, not only the governing law.

For EPC packages add one more: the decennial liability regime imposes a ten-year responsibility on contractors and designers for structural integrity, and it cannot be contracted away. It has to be insured and priced.

Power and water: the IWPP and IPP architecture

The UAE’s independent water and power producer model is one of the more successful pieces of procurement design in the region, and its documentation is now highly standardised. The shape is consistent: a purpose-incorporated project company, majority-owned by a state-linked entity with a developer-led international consortium holding the balance, selling capacity and output to a single creditworthy offtaker under a long-term purchase agreement, financed on limited recourse against that agreement.

The offtaker differs by emirate, and so does everything downstream of it. In Abu Dhabi, EWEC procures and offtakes utility-scale power and water within the Department of Energy’s framework. In Dubai, DEWA runs its own procurement and carries the offtake risk itself. The northern emirates are served through Etihad Water and Electricity. These are not interchangeable counterparties: tariff structures, approval processes, standard-form risk allocations and appetite for deviation from precedent all differ.

Bankability rests on a few provisions that reward disproportionate attention: the availability and capacity payment mechanism and what degrades it; change-in-law allocation, materially more consequential since federal corporate tax; fuel supply and its interaction with dispatch; force majeure relief; termination compensation, which is what lenders actually underwrite; and the step-in and direct agreement package. Because the documentation is templated, the temptation is to treat these as settled. On a solar bid at aggressive tariffs, one unpriced curtailment provision can consume the equity return.

Renewables, nuclear and the transition layer

Solar is the mature part of the transition story. The Mohammed bin Rashid Al Maktoum Solar Park in Dubai and the Al Dhafra and Noor projects in Abu Dhabi have produced some of the lowest recorded tariffs globally, on templated documentation with disciplined risk allocation. At those tariffs there is almost no margin for legal error: performance ratio guarantees, degradation curves, curtailment risk, grid connection timing and module supply — including the supply-chain diligence lenders now expect — carry the return. Corporate PPAs are growing but legally more variable, because the right to sell power directly to a private consumer depends on emirate-level regulation and is not uniform.

Nuclear is the one part of the sector where federal regulation is central. The Federal Authority for Nuclear Regulation is the independent federal regulator; the Emirates Nuclear Energy Corporation and its operating arm hold the programme; and the UAE’s policy commitment to forgo domestic enrichment and reprocessing shapes the fuel cycle and supply chain. For most clients the exposure is not reactor licensing but the contracting layer around it — nuclear-grade supply, quality assurance and code compliance, liability channelling, export control, and safeguards obligations that flow down to subcontractors who rarely expect them.

Hydrogen, ammonia and carbon management sit at the frontier, and the legal architecture is young. The offtake market for green molecules is predominantly export-driven, so structuring turns on long-term offtake credit, certification and origin-tracing standards set in the buyer’s jurisdiction, shipping and port logistics, and electrolyser supply and performance risk — rather than domestic regulation alone. For carbon capture and storage, bankability turns on ownership of pore space, long-term liability for stored CO2 after project life, and the measurement and verification regime. Existing UAE legislation does not comprehensively answer those questions, which means the contract does, or nothing does.

Decommissioning deserves its own line. There is no comprehensive federal decommissioning statute of the kind operators know from the UK or Norway. Abandonment and restoration obligations are principally creatures of the concession or licence and the contracts beneath it. Whether an outgoing participant remains exposed after assignment, how security for future liabilities is provided, and who carries residual liability decades after cessation are matters of drafting — and they are being tested now on assets entering late life.

Where energy mandates go wrong

The failure modes in this sector are consistent enough to list.

• Treating the UAE as one jurisdiction. A structure built for Abu Dhabi and re-used in Sharjah; a DIFC-governed document assumed to carry regulatory effect over an emirate-level licence. The most common structural error, and it surfaces at the approval stage, after the deal is announced.
• Imported boilerplate that does not survive UAE law. LOGIC and AIPN forms adopted with the governing law switched and nothing else changed. Liquidated damages a tribunal may adjust to reflect actual loss, blanket exculpation clauses, consequential-loss wording with no defined heads, and EPC packages priced with no allowance for decennial liability.
• Consent conditions treated as administrative. Approvals for assignment, change of control and security are substantive commercial risk. Long-stop dates set to a Western timetable, with no allocation of delay cost, put the transaction on the wrong side of a process nobody controls.
• ICV bolted on late. Local content commitments made at bid stage and reverse-engineered afterwards produce subcontracting structures that neither work commercially nor score well.
• Model contradicts contract. PSC-style cost recovery modelled against a participating-interest concession; a tax model ignoring how federal corporate tax meets emirate fiscal terms; a decommissioning provision that does not match the obligation actually drafted.
• Dispute clauses drafted last. Seat, institution, number of arbitrators, language, whether technical expert determination sits upstream — decided in the final hour and regretted three years later.
• No records regime. Services and construction disputes here are won on contemporaneous records. Notice obligations that do not specify what must be recorded, by whom and in what form, create claims that cannot be proved.

Disputes: an arbitration culture, and what it demands

Energy disputes in the UAE are overwhelmingly arbitral, for practical rather than ideological reasons: confidentiality, technical arbitrators who understand reservoir behaviour or turbine performance, English-language proceedings where the contract and evidence are in English, and — decisively — enforceability abroad. As a party to the New York Convention, the UAE offers a route to enforce and to have awards enforced across most relevant jurisdictions.

The institutions used in practice are the Dubai International Arbitration Centre, arbitrateAD in Abu Dhabi, and the ICC and LCIA where parties want a non-regional administrator. Seat selection is a real decision. A DIFC or ADGM seat brings a common-law curial framework and a supervisory court with a record in arbitration-related applications; an onshore seat brings the federal arbitration framework and onshore supervisory jurisdiction. Both work, not identically, and the choice should follow from where enforcement will actually be sought and against which assets.

Three patterns dominate. Gas price review and contract adjustment disputes, where long-tenor supply arrangements meet market movements the parties did not anticipate and the review clause bears more weight than its drafting supports. Delay, disruption and variation claims on EPC and services packages — records disputes dressed as legal disputes, turning on programme evidence, notice compliance and quantum methodology far more than liability theory. And joint venture and operating disputes: cash calls, sole risk, default and forfeiture, operator removal and audit rights, often under a document drafted decades ago for a different commercial world.

Because the relationships are long, the question is rarely just whether a claim succeeds, but whether the relationship survives it. Escalation and expert determination tiers resolve much technical disagreement before it becomes arbitration — but only when drafted as real conditions with defined triggers, not as a decorative preamble to the arbitration clause.

What to do next

If you are structuring a new position, fix the jurisdictional map before drafting: the emirate, the granting instrument, the approving bodies, the consent triggers and the fiscal architecture — then design the holding structure and contract suite around them.

If you are already contracted, three provisions repay immediate attention: the indemnity and insurance package as it interacts with UAE law rather than as drafted; change-in-law and tax, which most pre-corporate-tax contracts handle badly; and the decommissioning obligation on late-life or assigned assets.

If a dispute is forming, preserve the records before positions harden, test the dispute clause for enforceability against the assets you would actually pursue, and price the outcome before you price the argument. We act for international and national oil companies, service and EPC contractors, IPP and IWPP sponsors, lenders and export credit agencies, offtakers and government-linked entities — from structuring through to enforcement.

Frequently asked questions