The state exclusively owns all the deposits and natural accumulations of hydrocarbons in the soil and subsoil of Côte d’Ivoire as well as its territorial sea, its exclusive economic zone and its continental shelf, whether discovered or not discovered (Article 2, Petroleum Code). No person, including the owner of the surface, may undertake any operation unless such person has been previously authorised in accordance with the provisions of the Petroleum Code (Article 4).
The Ministry of Mines, Petroleum and Energy
The Ministry of Mines, Petroleum and Energy is responsible for the implementation and monitoring of the government’s policy on mines, petroleum and electricity. The ministry elaborates on and monitors the legislation and regulations in the field of hydrocarbons. Its mission is also the development of hydrocarbon exploration and exploitation activities, as well as co-ordination of the supply and distribution of oil products. It also controls the conformity of marketed oil and gas products to fight against fraud.
The General Directorate of Hydrocarbons
The General Directorate of Hydrocarbons (Direction Générale des Hydrocarbures or DGH) is one of the two Directorates of the Ministry of Mines, Petroleum and Energy. It is the government authority primarily responsible for the development and regulation of the oil and gas industry in Côte d’Ivoire. It is also mainly responsible for the research of hydrocarbon exploitation.
The Interdepartmental Petroleum Commission
The Interdepartmental Petroleum Commission (Commission Interministérielle Pétrolière or CIP) oversees the technical review of applications for petroleum authorisations and petroleum contracts. In addition to this, it also approves the lists of materials, chemical products and equipment that can benefit from the exemptions prescribed by Article 79 of Law No 96-669 of 29 September 1996, on the Petroleum Code (exemption from all import duties and taxes, including VAT). The CIP is also governed by Title XI of Decree No 96-733 of 19 September 1996, on the general application of the Petroleum Code.
Côte d’Ivoire has a national company, PETROCI Holding (95% owned by the state and 5% owned by employees), which has three subsidiaries: PETROCI Exploration-Production, responsible for upstream hydrocarbon activities; PETROCI-Gaz, responsible for development of the gas sector; and PETROCI Industries-Services, responsible for all other related services.
In this respect, the state supervises and participates in the oil and gas industry through the national company, PETROCI Holding and its subsidiaries. Oil and gas operations (onshore and offshore) are therefore undertaken mostly by the state itself, through PETROCI or by companies or joint ventures that have entered into a contract with the state for this purpose. The Petroleum Code grants the state the right to acquire an interest, directly or through state entities, in petroleum operations carried out under a petroleum contract, subject to the terms and conditions of the petroleum contract. The Petroleum Code does not provide any further details or thresholds or minimum rates, but the state’s participation, through the state entity PETROCI, is generally set between 10% and 15%.
The Société Ivoirienne de Raffinage (SIR), the only Ivoirian oil refinery, and its associated storage company, GESTOCI, sell refined oil. The market for petroleum products is not liberalised, so companies seeking to market petroleum in Côte d’Ivoire must do so through SIR and the Ministry of Petroleum, Energy and Renewable Energy.
The Petroleum Code and Legislation
Hydrocarbon is governed by Law No 96-669 of 29 August 1996 on the Petroleum Code, as modified by Ordinance No 2012-369 of 18 April 2012 for all upstream, midstream and downstream operations. This law governs hydrocarbon prospecting authorisation, petroleum contracts for hydrocarbon research and exploitation, hydrocarbon research and exploitation authorisation, as well as authorisation to transport hydrocarbons by pipeline, and customs tax and exchange regulations.
The following main legislation governs the Petroleum Code’s application as well as the types of authorisations and permits available.
The Petroleum Code is currently under revision but in its early stages without specification as to what will be changed.
In addition, the legal framework governing local content has been substantially reinforced. Law No 2022-408 of 13 June 2022 on local content in oil and gas activities is implemented by Decree No 2023-441 of 24 May 2023. This decree defines local content obligations and performance indices (local expenditure, local goods, local services and local staff), preferences for Ivorian companies, hiring thresholds by activity phase, and sanctions in case of non-compliance.
Several supplementary texts were adopted in 2024, including:
Finally, a new digital platform for local content was also created last year by Order No 137 /MMPE/DGH of 15 April 2024 on the creation and operation of the digital platform dedicated to local content in oil and gas activities in Côte d’Ivoire. This digital platform also makes it possible to dematerialise all the procedures for applying for or renewing authorisations, and to monitor and evaluate the state’s policy on local content in oil and gas activities in Côte d’Ivoire. Any oil company, oil subcontractor, service provider or supplier of goods and services for oil and gas activities is required to register on the said digital platform dedicated to local content. Registration on the digital platform dedicated to local content is annual and subject to payment of a registration fee. Related regulation has been listed in 7.4 Material Changes in Law or Regulation.
Pooling and Unitisation Rules
Article 56 of the Petroleum Code provides that if a hydrocarbon deposit extends over several contractual perimeters allocated to separate holders, the latter may be required, where appropriate, to enter a so-called “unitisation agreement” in order to exploit the deposit under the best technical and economic conditions. This agreement and the joint exploitation plan must be submitted to the government.
This will be governed by commercial and contract law between the companies wanting to share the same exploitation on the same surface. The state is always a party to the contracts governing upstream, midstream and downstream operations. However, the Decree of Application prescribes that if multiple companies were to present an application for an authorisation, these companies must act jointly and severally for oil operations. They must provide proof of the joint and several nature of their action in a contractual document also defining the terms and conditions of execution of the petroleum operations. The application must designate which of the companies will act as operator within the meaning of Article 8 of the Petroleum Code (Article 10.2, Decree of Application). One of these companies can be from another domain rather than specifically petroleum.
Foreign private investments are allowed in Côte d’Ivoire. The contracts need authorisation from the state to carry out oil and gas activities. The terms of this authorisation are prescribed in a petroleum contract between the contractor and the state. The government has discretionary power to grant authorisation and agree to the contracts.
Article 8 of the Petroleum Code prescribes two requirements. On the one hand, foreign operators must justify a permanent establishment, through a local subsidiary for the whole duration of the petroleum contract or through a branch. If the foreign operators choose to open a branch for this operation, such branch must be transferred to a local entity within two years of registration. On the other hand, all eligible companies must be able to demonstrate sufficient technical, financial and legal capacity to undertake oil and gas operations.
The various licences and contracts are as follows.
Foreign direct investments must be declared to the Ministry of Economy and Finances, to allow dividends and other income from the investment to be expatriated.
Process for Obtaining Authorisation (Article 10, Decree of Application of Petroleum Code)
All applications for authorisation to explore for hydrocarbons or for a petroleum contract must include the specific information prescribed by Article 10, such as:
Authorisation to explore for hydrocarbons in areas not covered by a petroleum contract may be granted by government decree, setting out the conditions. Prospecting authorisations are granted for a maximum of one year and may be renewed once for a year. This is not a mining title and is neither assignable nor transferable (Article 11, Petroleum Code).
Prospecting authorisations do not entitle the holder to enter a petroleum contract (subject to exemptions). The results of prospecting work are communicated to the government under the conditions set out in the decision. The state may at any time enter into a petroleum contract for all or part of the perimeter covered by a prospecting authorisation, which automatically lapses for the area concerned, without entitling the holder to any compensation (Article 12, Petroleum Code).
Exemptions apply:
For this application to be admissible, it must be submitted fulfilling all requirements previously prescribed and must relate to only those areas open to exploration and exploitation (Article 11, Decree of Application of Petroleum Code).
For prerequisite qualifications, see 2.1 Forms of Private Investment: Upstream. A company can be a branch of another company but must provide all the details of the parent company as well as the protocols, statutes or contracts governing its relationship with the parent company regarding petroleum operations.
For a single application submitted by multiple companies, see 1.4 Principal Hydrocarbon Law(s) and Regulations.
Petroleum contract holders are subject to an annual surface fee where the amounts are established in the contract (Article 68, Petroleum Code).
Article 69 of the Petroleum Code provides as follows.
Companies are subject to the payment of taxes under the General Tax Codeand fees (Article 66, Petroleum Code) due to the upstream operations and activities of research and exploitation (downstream). Taxation in the oil sector is both upstream and downstream. Upstream taxation is governed by the Petroleum Code and production sharing contracts.
Goods and services not directly assigned to petroleum operations, and therefore not eligible for deduction under the provisions of Articles 224 et seq of the General Tax Code, are excluded from the above-mentioned VAT exemptions. Exemption from VAT, tax on the provision of services and advance payment on various taxes apply under the same conditions to companies subcontracted to extract oil.
No special rights are given to national companies in connection with upstream licences. There is no right to take over but, after research operations, the state can benefit from any discovery made during the research phase.
Law No 2022-408 of 13 June 2022, on Local Content in Oil and Gas Activities is a recent law that governs everything relating to local content. The purpose of this law is to promote and develop local content in oil and gas activities in the Republic of Côte d’Ivoire, to maximise added value and job creation in oil and gas activities through the use of local expertise, local goods and services, and Ivorian companies; to develop local capacities in the oil industry value chain (education, training, skills development and transfer, technology transfer) and know-how as well as research and development; and to promote the competitiveness of national and international Ivorian companies and the development of a national industrial fabric (Article 3).
See 4.1 Foreign Investment Rules Applicable to Domestic Investments in Hydrocarbons on imports and 7.4 Material Changes in Law or Regulation for the latest updates in this area.
Exploitation
The holder of a hydrocarbon exploration authorisation who has provided proof, through research, appraisal and delimitation work carried out in accordance with the present law, of the existence within its perimeter of a commercially exploitable hydrocarbon deposit will be entitled, in the event of an application in due form submitted before the expiry of the validity of its exploration authorisation, extended, where applicable, under the conditions of paragraph 3 of Article 22, to obtain an operating authorisation relating to this deposit (Article 34, Petroleum Code).
Article 34 prescribes that such application must be accompanied by a draft development and production plan for the deposit, submitted to the government, which must include:
The application must also designate the oil company acting as operator, which is required to justify its technical, financial and legal capacities, and which will have duly demonstrated satisfactory experience as an operator in similar areas and conditions. The holder must undertake to carry out the development work on the commercial deposit with all possible diligence, in accordance with the development plan and any amendments thereto.
During the period of validity of a hydrocarbon exploration authorisation, only the holder may obtain an operating licence within the perimeter of the exploration authorisation (Article 34, Petroleum Code).
The operating licence may only be granted to an oil company with proven technical, financial and legal capabilities, and which has duly demonstrated satisfactory past experience as an operator in similar areas and conditions. The operating licence is granted by decree.
The granting of an operating licence in no way confers ownership of the deposits; it creates a time-limited right, upon which no mortgage can be placed, distinct from surface ownership, which is transferable and assignable under the conditions laid down in the present law (Article 31, Petroleum Code).
Exploration
The exploration authorisation is granted by a government act, for an initial period of validity of up to three years, renewable in accordance with the provisions of Article 22 under the terms of the petroleum contract, which will previously have been concluded with the state. However, in the case of production sharing contracts or risk service contracts, the signing of the contract is equivalent to the granting of exclusive exploration authorisation (Article 21, Petroleum Code).
The licensee must have fulfilled all its obligations during the current validity of its hydrocarbon exploration licence, which it will be able to renew twice. This is done through an act of government.
The initial duration of the research authorisation, plus the duration of the two renewals, may not exceed seven years, or nine years in deepwater marine areas, not including the duration of any extension referred to in the last paragraph of Article 22. On the date of each renewal, the area of authorisation is reduced in accordance with the oil contract. The period of validity of the authorisation may be extended under the conditions laid down in the contract, by government act, in case of necessity to allow the completion of exploration drilling in progress or the evaluation and delimitation of a hydrocarbon discovery, particularly in the case of a discovery of non-associated natural gas or a discovery located in deep marine zones (Article 22, Petroleum Code).
As soon as the existence of a commercially exploitable hydrocarbon deposit has been established, the holder of the exploration permit is required to apply for an exploitation permit and to undertake development and exploitation activities. The granting of an exploitation authorisation cancels the research authorisation within the exploitation perimeter, but leaves it in force outside this perimeter until its expiry date, without modifying the minimum programme of research work subscribed to by the holder (Article 26, Petroleum Code).
Prospecting authorisations are granted for a maximum period of one year and may be renewed once for a maximum period of one year. The authorisation is not a mining title and is therefore neither assignable nor transferable (Article 11, Petroleum Code).
Assets can be transferred between private investors. Capital gains arising from the sale or transfer of any assets must be credited to the production and profit and loss account referred to in Article 70. However, if the operation is carried out by several associated companies, in the event of a transfer between the associated companies or between one of the associated companies and one of its subsidiaries, which would become a party to said operation, capital gains on the transfer are excluded, provided that the assets thus transferred are booked by the transferee company at the value appearing in the books of said company.
Article 28 of Decree No 96-733 of 19 September 1996, on the general application of the Petroleum Code, prescribes that if the holder of a petroleum contract wishes to assign or transfer to its subsidiary or to a third-party company, directly or indirectly, all or part of the rights and obligations resulting from the contract, it must submit the request to the competent administrative department in accordance with the provisions of Article 38 of the Petroleum Code, in French, in accordance with Article 4, which will acknowledge receipt after having registered them in the special register. If the assignment or transfer is authorised by the competent administrative authority, a decree is issued by said authority. This provision does not apply in the event of assignment or transfer between entities that are a party to the petroleum contract, except for the operator. Any such assignment or transfer must be duly notified to the competent administrative department.
There are no restrictions on production rates established by Ivorian laws. Production has not yet reached the goal planned by the state of 200,000 barrels a day. The oil sector in Côte d’Ivoire is, however, on the rise, both onshore and offshore.
Midstream/downstream private investment is through an authorisation system granted by the state and the relevant authorities. The gas imported into Côte d’Ivoire is stored in private facilities with high capacities located in the national territory. Only public companies such as PETROCI and SIR are authorised to import such gas. Distributors purchase from these facilities and then store the gas for sale in their own facilities. Import, export, processing, storage and transport, as well as distribution, of petroleum products are subject to prior authorisation (Article 2 of Law No 92-469 of 30 July 1992, on the repression of fraud involving petroleum products and violations of technical safety requirements). There is no restriction on foreign investment in this area. There is no monopoly except for the import of gas.
Storage
The opening and operation of these storage facilities are subject to authorisation under the following conditions:
Authorisations for new installations are nominative and transfers are subject to new applications.
To be approved, the petroleum depot must comply with the technical and safety regulations in force. The commissioning of the petroleum depot is subject to obtaining an operating authorisation issued after noting that the depot or establishment complies with the plan attached to the application and with the technical regulations in force (particularly regarding fire safety). In this respect, the violation of the technical and safety regulations relating to the handling and storage of petroleum products constitutes an infraction under Law No 92-469 of 30 July 1992, on the repression of fraud involving petroleum products and violations of technical safety regulations.
Finally, other decrees regulate the storage of gas, including regulations related to the construction and safety arrangements during the operation of liquefied hydrocarbon deposits stored at a temperature above 0°C. There are also specific texts regarding equipment for the production, storage or use of compressed, liquefied or dissolved gases.
For details on transport, see 3.3 Issuing Midstream/Downstream Licences.
In the case of hydrocarbon production subject to sharing contracts, the production is shared between the state and the contractor in accordance with the provisions of the contract. The production, referred to as “cost oil”, cannot be higher than the percentage of the production fixed in the contract. The contract will define the recoverable oil costs and terms and conditions for their recovery from production. It will also specify whether the sharing is carried out before or after tax on industrial and commercial profits.
As said above, the import, export, processing, storage, transport and distribution of petroleum products are subject to prior authorisation (Article 2 of Law No 92-469 of 30 July 1992, on the repression of fraud involving petroleum products and violations of technical safety requirements).
Midstream, or the transportation of hydrocarbons, is governed by Title V of the Petroleum Code (see also 3.10 Laws and Regulations Governing Transportation).
The holders of oil contracts, or each of their co-holders, have the right, during the validity of the contract and under the conditions laid down in the Petroleum Code, to transport in their own installations, within the territory of the Republic of Côte d’Ivoire, its territorial sea, its exclusive economic zone and its continental shelf, or to have transported while retaining ownership, the products resulting from their exploitation activities or their part of said products to the points of collection, treatment, storage, loading or major consumption (Article 40, Petroleum Code). These rights, including the authorisation provided for by that same law (detailed further on in this chapter), may be transferred individually or jointly by the holders of an oil contract under the conditions laid down in the regulations and the contract. Any transfers to a third party are subject to prior authorisation and granted by an act of the government. Beneficiaries of these transfers must satisfy the conditions laid down by said law and its implementing texts for the construction and operation of the pipelines and facilities concerned.
The authorisation to transport hydrocarbons by pipeline is granted by decree. It includes approval of the pipeline and facility construction project attached to the application and declares the project to be in the public interest. The transport authorisation also entitles the holder to install pipelines and facilities on land not owned by the holder. The land required for the pipelines and installations is occupied under the conditions laid down in Title VI of the Petroleum Code.
It is important to note that the authorisation to transport hydrocarbons lapses if the holder of the petroleum contract or the beneficiaries of the transfers referred to above have not started or initiated the planned work one year after approval of the project (Article 44, Petroleum Code).
The concession contract is concluded prior to the granting of a hydrocarbon exploration permit. It sets out the rights and obligations of the state and the holder during the period of validity of the exploration permit and, in the event of the discovery of a commercially exploitable hydrocarbon deposit, during the period of validity of the exploitation concession. The holder of the concession contract assumes the financing of petroleum operations at its own risk and disposes of the hydrocarbons extracted during the period of validity of the contract, in accordance with the contract (Article 14, Petroleum Code).
Holders of these concession contracts, referred to in Article 14 above, are required to pay a monthly royalty proportional to production. The rate of this royalty, as well as its assessment and collection rules, which may be different for liquid and gaseous hydrocarbons, are specified in the concession contract. The royalty is paid in kind or in cash, in accordance with the terms specified in the contract. The concession contract may provide for total or partial exemptions from the production royalty in exceptional cases, with a view to promoting oil operations in the Republic of Côte d’Ivoire, particularly in deepwater marine areas (Article 69, Petroleum Code).
Depending on their nature, petroleum operations under a production sharing contract are covered by an exclusive authorisation either for exploration (and, in the event of a discovery, appraisal), or for the exploitation of a commercially exploitable hydrocarbon deposit (Article 15, Petroleum Code).
Other fees payable by petroleum establishments and service stations, due annually, are royalties for occupation of the state’s public and private domain (Ordinance No 61-183 of 18 May 1961, modified by Law No 79-1048 of 27 December 1979; Law No 2020-972 of 23 December 2020, fiscal annum, Article 11. Property rights and land registration, text 3).
The oil contract holders or companies are subject, under the conditions set out in the Petroleum Code, to direct industrial and commercial income tax on the net profits they derive from all their hydrocarbon exploration and production activities, including transport, in the territory of the Republic of Côte d’Ivoire, its territorial sea, its exclusive economic zone and its continental shelf, whether alone or in association with other companies (Article 70, Petroleum Code).
To this end, each petroleum contract holder or company, whatever its nationality, must keep separate accounts for each fiscal year for its petroleum operations in Côte d’Ivoire, making it possible to draw up a production and profit and loss account, and a balance sheet showing both the results of said operations and the assets and liabilities assigned to them or directly related to them.
The taxable net profit referred to above is made up of the difference between the net asset values at the end and beginning of the financial year, less any additional contributions and plus any withdrawals, by the company or its partners, made during the financial year. Net assets are defined as the excess of asset values over the total of third-party receivables, authorised or justified depreciation and provisions on the liabilities side.
The undischarged amount of the deficit that the company proves to have incurred in respect of oil operations may be deducted from taxable profit beyond the limited carry-forward period provided for in the General Tax Code, until the deduction is made in full.
Taxes
Under the General Tax Code (Impot sur les Benefices Industriels et Commerciaux or BIC), the corporate income tax rate is 25%. The state’s share of production includes the BIC payable by the oil and gas company, as per the Petroleum Code and the production sharing contract. The Petroleum Code provides that petroleum contracts may allow for signature and production bonuses. Under the General Tax Code, specific rates apply for companies producing, processing and selling petroleum products, companies producing and distributing water and electricity, and companies distributing butane gas, this rate standing at 0.10% (Article 39). Under the General Tax Code, the following applies:
In addition, the petroleum contract may include a “signature bonus”, which the contract holder undertakes to pay to the state for concluding the contract, and a “production bonus”, which the contract holder undertakes to pay to the state according to the quality of hydrocarbons produced.
When the petroleum concession contract refers to Article 14 of the Petroleum Code, the holder may be subject to an additional petroleum levy calculated on the profits from petroleum operations, in accordance with the stipulations of the applicable contract.
Exemption
Except for the tax on industrial and commercial profits referred to in Article 70 of the Petroleum Code and, where applicable, the production royalty, additional oil levy and other taxes referred to in Articles 67, 68, 69, 74 and 75, the oil contract holder is exempt from:
Oil and gas exploitation taxes
Applications for the award, renewal, assignment, transfer or waiver of petroleum contracts and the authorisations deriving therefrom are subject to payment of fixed entry fees and are payable at the conclusion of each award or transaction. There is also an annual surface royalty, the amount and payment terms of which are set forth in the relevant oil contract.
It is important to note that oil and gas contract holders are mostly exempt from the payment of other taxes on profits or dividends paid to shareholders, and any other tax or contribution based on operations, activities, assets and profits derived therefrom, as well as VAT on the provision of services and advance payments introduced by Law No 90-434 of 29 May 1990.
No special right is given to domestic companies regarding midstream and downstream activities, except for the special equipment tax described in 3.5 Income or Profits Tax Regime: Midstream/Downstream.
See 2.6 Local Content Requirements: Upstream, 4.1 Foreign Investment Rules Applicable to Domestic Investments in Hydrocarbons and 7.4 Material Changes in Law or Regulation for the latest updates in this area.
The holder of an oil contract is required to provide the government with information, data, documents and samples originating from or resulting from oil operations, as well as the periodic reports provided for by the regulations and the oil contract. These reports are confidential and may only be made public in accordance with the conditions laid down in the texts implementing the present law and the oil contracts (Article 50, Petroleum Code).
The holder of a petroleum contract may, under its own responsibility, subcontract the petroleum operations for which it is responsible to qualified companies. For the purposes of the operations entrusted to them and within this limit, subcontractors have the same rights and obligations as the oil contract holder. Subcontracts must be communicated to the government (Article 51, Petroleum Code).
The Petroleum Code does contain provisions on the regulation of relations with landowners (Title IV, Chapter 2 on land use and relations with landowners and third parties). As a result, relations with landowners and the occupants of the land are governed by the laws already applied.
Except in the case of special authorisation, the holder of an oil contract may not occupy any of the following lands or carry out work of any kind thereon (Article 60, Petroleum Code):
Article 61 governs the rights of landowners. The occupation of land and the exercise of the rights referred to in Article 59 of the Petroleum Code by the contract holder will be the subject of agreements between the oil contract holder and the owners of the land or the beneficiaries of customary rights. In the absence of an amicable agreement, the government may grant the holder temporary occupation or use authorisations in order not to delay the normal course of oil operations, without prejudice to the legitimate rights of the landowners or the beneficiaries of customary rights. At the same time, this authorisation fixes a provisional and approximate compensation for occupation, which must be deposited prior to taking possession, and which constitutes a down payment on the compensation referred to in Article 62 of the same code (see further on in this chapter).
The occupation of land belonging to private individuals entitles them to an annual indemnity equal to the sum representing the value of the net product of the land prior to occupation. Where such occupation deprives the owner of enjoyment of the land for more than two years, or where after completion of the work the land occupied is no longer suitable for its previous use, the owner may require the holder of the oil contract to acquire the land. The land to be acquired in this way is always valued at the sum representing, at the time of acquisition or redemption of the use rights, the value of the land or said rights prior to occupation. The occupation of registered land in the private domain of the state and other public bodies, which is not already legally occupied by third parties, is carried out without compensation (Article 61, Petroleum Code).
The completion of petroleum operations and related installations may, if necessary, be declared to be in the public interest and urgently required, at the request of the holder of the petroleum contract, in accordance with the applicable legislation. Where necessary, expropriation may be carried out for this purpose, and the oil contract holder will bear the costs, compensation and charges resulting from the expropriation procedure. This declaration is granted by decree issued on the proposal of the government (Article 62).
However, the state may at any time enter a petroleum contract on all or part of the perimeter covered by a reconnaissance authorisation, which automatically lapses for the area concerned, without entitling the holder to any compensation (Article 12, Petroleum Code).
Title V of the Petroleum Code governs any transport of hydrocarbon by pipelines. The Ministry of Oil, Gas and Energy is the regulatory body governing transportation.
Authorisations for the transportation and distribution of oil production by pipeline to the various points of collection, processing, storage, loading or bulk consumption must be submitted separately by contractors and are granted by decree. The oil contract holder can, during the contract and within the conditions stipulated in the Act, transport within their own facilities in Côte d’Ivoire, its waters, its economic zone, and its continental shelf towards the various points of collection, treatment, stock, or bulk consumption (Article 40).
Violating the technical safety regulations relating to transport of petroleum products constitutes an infraction under Law No 92-469 of 30 July 1992, on the repression of fraud involving petroleum products and violations of technical safety regulations.
There is no reference to third-party access to infrastructure in the Petroleum Code.
In the case of commercial production of hydrocarbons, the holder of a petroleum contract must give priority to allocating a share of its production to meeting the needs of the Ivorian domestic market. The terms and conditions of this obligation are specified in the oil contract, including the transfer price. Once the country’s domestic consumption needs have been met, if applicable, the oil contract holder is free to dispose of the share of hydrocarbon production to which it is entitled under the contract. The conclusion of a contract in no way confers the right to refine or process hydrocarbons and/or to sell products derived therefrom, unless expressly authorised by the state (Article 55, Petroleum Code).
Import
Oil contract holders and their subcontractors have the right to import into the Republic of Côte d’Ivoire the materials, chemical products, machinery and equipment required to carry out oil operations under the approved work programme, free of all import duties and taxes, including VAT. This import exemption also extends to parts and spare parts for machinery and equipment required for oil operations.
A list of the materials, chemicals, machinery and equipment eligible for these exemptions is drawn up by the government, after consulting an approval commission. This list, which is appended to the petroleum contract, is revised periodically to take account of technical developments, in agreement with the competent authorities and the approval commission (Article 79.5, Petroleum Code). This right is subject to Article 52 of the Petroleum Code, specifying that the holder of an oil contract and its subcontractors must give preference to Ivorian companies for construction, supply and service contracts, under equivalent conditions of quality, price, quantity and delivery times.
Since the entry into force of Law No 2022-408 and Decree No 2023-441, the legal framework has also reinforced the application of local content rules to procurement processes, including for imported goods and services. Article 12 of Decree No 2023-441 requires oil contract holders and their subcontractors to give preference to Ivorian suppliers in the procurement of goods and services, provided that these are of equivalent quality, price and delivery conditions. Compliance with this provision is now monitored through the dedicated online platform launched by the DGH in June 2024.
Export
Imports and exports are subject to all the formalities required by the Customs Administration for the import of goods intended for petroleum operations, and to dispense with qualitative and quantitative inspection and price comparison for materials, machinery and equipment intended for petroleum operations (Article 79.5, Petroleum Code).
Holders of petroleum contracts have the right to export, free of all duties and exit taxes, the fraction of hydrocarbons to which they are entitled under petroleum contracts (Article 80, Petroleum Code).
See also 7.2 Liquefied Natural Gas (LNG).
Conditions
The petroleum contract must set out conditions for the assignment and transfer of the contract and the authorisations deriving therefrom. The rights and obligations under a petroleum contract, as well as the exploration authorisation and the hydrocarbon exploitation authorisations deriving from the contract, are assignable and transferable subject to the prior approval of the government and under the conditions laid down by the regulations and the applicable contract, which may lay down special conditions in the event of assignment or transfer to an affiliated company or between co-holders.
The holder of the oil contract must notify the government, for approval, of any contract or agreement by which it promises to entrust, assign or transfer, or by which it entrusts, assigns or transfers, in whole or in part, the rights and obligations arising from the oil contract. The same applies to any transaction resulting in a change of control of the owner company.
Any such agreement may only be entered into subject to the suspensive condition of such approval. Any act carried out in violation of the provisions of Article 38 is null and void and may not result in the termination of the oil contract.
The assignee must satisfy the conditions laid down by the present law, its implementing texts and, where applicable, the oil contract.
Withdrawals
When an oil contract is concluded with several joint holders, the withdrawal of one or more of them does not entail the cancellation of the authorisations deriving from the contract, nor the termination of the contract, if the other holder or holders take over the commitments which had been subscribed for the said contract. This withdrawal is accepted by the government (Article 38, Petroleum Code).
Authorisation
When it comes to transport, these rights, including the authorisation provided for in Article 43 of the Petroleum Code, may be transferred individually or jointly by the holders of an oil contract under the conditions laid down in the regulations and the contract. Any transfers to a third party are subject to prior authorisation and granted by an act of the government. Beneficiaries of those transfers must satisfy the conditions laid down by the present law and its implementing texts for the construction and operation of the pipelines and facilities concerned (Article 40, Petroleum Code).
Foreign Investment Review Processes and Incentives
The Petroleum Code provides some protection against expropriation. If an authorisation is not issued within a year, the state can withdraw this authorisation from the applicant for efficiency reasons. Even though the land does not belong to the interested company, some might be living on and occupying the land in question. The company has a right of way, and the occupants may not hinder the work done by the company (Article 43, Petroleum Code).
In principle there are no restrictions, but, as stated previously (see 2.1 Forms of Private Investment: Upstream), foreign companies must demonstrate, throughout the duration of the petroleum contract, the existence of a permanent establishment in Côte d’Ivoire registered in the trade register. It can be a company under Ivorian law or a branch office.
International Laws and Arbitration
Contracts are governed by Ivorian laws; however, any arbitration clause can be introduced at the will of the parties involved, the state and the company exploring or exploiting.
Local Trends
There are no local trends to restrict or block foreign investments in hydrocarbons. Many foreign companies have invested in Côte d’Ivoire in this industry. Some, like Total or ENI, have sharing contracts with the government, represented by PETROCI Holdings. There is a genuine interest in foreign investments, with Côte d’Ivoire aiming to increase foreign investment in the economy.
In addition, the government’s economic agenda explicitly promotes foreign investment as a catalyst for energy transition. Foreign investors are encouraged to engage in hybrid and gas-to-power infrastructure projects, which benefit from fiscal incentives and simplified permitting procedures under ongoing regulatory reforms. The EU-funded Green Energy Production Support Programme (Programme d’Appui à la Production d’Énergies Vertes or PAPEV programme) and some climate-aligned financing instruments are also opening new opportunities for foreign participation in the renewable energy components of oil and gas operations.
Except for countries under oil embargo or under international sanctions, there are no restrictions or sanctions in Côte d’Ivoire for investing in oil and gas assets in certain jurisdictions or with some foreign counterparts or governments.
The National Environment Agency (l’Agence Nationale de l'Environnement or ANDE) is the environmental authority tasked with supervising, validating and controlling all activities relating to the environmental impact assessment (EIA) of development projects. The EIA must be approved by the minister of the environment before the project is implemented.
Legal Regime
Under Article 39 of the Environment Code and Annex I of Decree No 96-894, oil and gas projects are subject to an EIA prior to their implementation. The content of this EIA is set out in Article 40 of the Environment Code and Article 12 of the Decree No 96-894. The operator is responsible for the EIA. It must be carried out by environmental study offices approved by ordinance of the minister in charge of the environment (Article 10, Ordinance No 00972-2007).
The project is controlled and monitored carefully to verify the relevance of the forecasts and adopt the necessary corrective measures. Six months after the implementation and operation of the activities of a development project, an environmental audit completes the environmental monitoring following the EIA. This is done without interrupting the course of this environmental monitoring (Article 18 of No 00972-2007). The examination of environmental impact studies by the Bureau d’Etudes d’Impact Environnemental (Office of Environmental Impact Studies) will give rise to the payment of a fee to the Fonds National de l’Environnement (National Environment Fund), the basis of which will be specified by decree (Article 41, Environment Code).
The oil contract holder must, in the context of its activities, comply with the following principles:
The holder of the petroleum contract must perform all operations and work using the techniques in use in the international oil industry and ensure the conservation of natural resources, including hydrocarbon deposits; the protection of the essential characteristics of the environment; and take all measures to preserve and protect the natural environment and ecosystems (Article 49, Petroleum Code). The exploitation and management of oil resources must take into account the protection of the environment as well as preserving the interests of future generations (new Article 82 of the Ordinance No 2012-369 of 18 April 2012, amending the Petroleum Code).
Finally, Decree No 2013-851 of 19 December 2013 established an exclusion and a safety zone around oil and gas drilling, exploration and production equipment, and seismic survey vessels. A perimeter of one nautical mile (1.845 km) is declared an exclusion and safety zone for navigation and fishing around drilling, research and oil and gas production equipment and related facilities, as well as around seismic survey vessels.
Sanctions
Criminal sanctions are provided for in the Environment Code. Falsification, failure to carry out an EIA, failure to comply with the specifications for the EIA or failure to use an approved environmental study office are punishable by criminal penalties (Article 92 of the Environment Code and Articles 29 to 36 of Ordinance No 00972-2007).
The operator pays ANDE a fee of XAF20 million (Article 27, No 00972-2007).
See 5.1 Environmental Laws and Environmental Regulator(s). All the requirements for major hydrocarbons projects are set out in the Petroleum Code and its decrees. An EIA will be monitored and controlled by the ANDE.
No specific EHS requirements apply to offshore development. Holders of petroleum contracts must ensure that health and safety standards are applied in accordance with the applicable standards in the international oil industry. These standards must be applied both on their own behalf and on behalf of their subcontractors. Any serious accident must be reported immediately to the competent authorities (Article 54, Petroleum Code). Measures must be taken to preserve and protect the safety of persons and property (Article 49, Petroleum Code).
Under the exploitation authorisation, either in its standard term or in the case of renunciation or withdrawal, the petroleum contract holder must, unless otherwise agreed by the government, undertake, at its own expense, the abandonment operations prescribed by the regulations and the petroleum contract. The contract holder must also provide the state with all the information and petroleum data in its possession concerning the abandoned area (Article 29, Petroleum Code).
An application for an operating licence for this deposit is accompanied by a draft development and production plan for the deposit submitted to the government, which must include an abandonment plan (Article 34, Petroleum Code).
The abandonment operations include (Article 1, Ordinance No 2012-369 of 18 April 2012, amending Law No 96-669 of 29 August 1996, on the Petroleum Code):
The operator must set aside a decommissioning provision as per the terms and conditions set out in the petroleum contract. The installations, equipment and land relating to the authorisation, which are necessary for the continuation of the exploitation, are, at the request of the government, transferred to the state, without any compensation to the holder (Article 37, Ordinance No 2012-369).
There are no climate change laws in effect that provide specific regulations for the oil and gas industry.
However, in its plan towards a more sustainable future, Côte d’Ivoire has adopted sustainable modes of production and consumption. Côte d’Ivoire does not have a carbon tax, but this change is part of a strategy to reduce its carbon emissions. The state demonstrated its commitment towards sustainable development by the enactment of Law No 2014-390 of 20 June 2014, on sustainable development (the “Sustainable Development Law”). This law applies to the energy sector and aims to merge principles of sustainable development into the activities of public and private actors (Article 8, Sustainable Development Law).
This law implements multiple principles to ensure sustainable strategies including a “polluter pays” principle (item 5.10, Sustainable Development Law). It further provides that the state will develop and implement tools to fight climate change. As a result, the private sector must apply these principles and must report periodically on how this sustainable development plan is being implemented (Articles 37, 38 and 39, Sustainable Development Law).
The state may limit oil and gas development by enacting laws. The state is heavily involved in the exploitation of oil and gas, and the granting of authorisations. It may, as a result, restrict the granting of those authorisations, or change the processes and required elements to grant them.
The ECOWAS Bioenergy Policy (EBP) was adopted by the ECOWAS states in December 2016 and by the ECOWAS heads of state on 4 July 2017. Côte d’Ivoire, being a member, followed suit with the Côte d’Ivoire National Bioenergy Action Plan over the Period 2020 to 2030 to implement the EBP. Together, these are known as the ECOWAS Bioenergy Policy and Bioenergy Action Plan (EBPP).
In addition to this plan, Côte d’Ivoire enacted another plan, the National Renewable Energy Action Plan (PANER) Côte d’Ivoire, over the period 2016–2020 and on to 2030, as part of the implementation of the ECOWAS Renewable Energy Policy (PERC).
Renewable energies in Côte d’Ivoire are part of a vision of sustainable development through the adoption of sustainable modes of production and consumption to include communities in low-carbon growth strategies. The development of the renewable energy sector in Côte d’Ivoire for electricity consumption is based on three distinct sources. Firstly, exploiting the large potential for hydroelectricity, estimated at 1,680 MW, including large, medium and small hydroelectricity producers, and secondly, using the national potential for biomass, estimated at more than 12 million tonnes/year. (In addition to their economic appeal, biomass techniques have the advantage of operating like basic thermal units, which makes the system easier to operate.) Finally, the planned development of the country’s photovoltaic solar potential, with average annual sunshine on a horizontal plane presenting a potential of 5.25 kWh/m²/d (Côte d’Ivoire National Bioenergy Action Plan and National Renewable Energy Action Plan (PANER) Côte d’Ivoire).
Several national regulations and sectoral policies have been adopted to regulate the energy sector in Côte d’Ivoire, including:
Rural electrification is one of the major thrusts of the Ivorian government’s economic and social policy, with the aim of achieving total electrification of Côte d’Ivoire by 2025. The policy to achieve this is set out in the National Rural Electrification Programme (PRONER), adopted in July 2013.
Biofuels are not specifically regulated but are currently covered by the legislation mentioned above. No specific law has been enacted regarding energy transition in the country.
In Côte d’Ivoire, no specific action has been taken by oil and gas upstream/midstream assets in connection with energy transition projects. No explicit plan of action has been applied and actioned to enable energy transition projects such as CCUS, RNG, SAF or hydrogen production.
However, in a regional initiative, an ECOWAS Green Hydrogen Policy and Strategy Framework has been published, of which Côte d’Ivoire is a member.
It is understood that energy transition considerations are governed by the Sustainable Development Law (see 5.5 Climate Change Laws) but there are no specific guidelines regulating greenhouse gas emissions.
As described in both 6.1 Energy Transition Laws and Regulations and 6.2 Energy Transition and Oil and Gas Development, it is understood that energy transition considerations are governed by the Sustainable Development Law (see 5.5 Climate Change Laws) but there are no specific guidelines regulating greenhouse gas emissions.
As of the publication of this guide (August 2024), no legislation relating to unconventional upstream interests has been enacted.
There is no regulation enacted relating to LNG projects as of the publication of this guide (August 2024).
There are no particularities of the hydrocarbon industry in Côte d’Ivoire.
The latest update in oil and gas law in this jurisdiction is Decree No 2023-441 of 24 May 2023, implementing Law No 2022-408 of 13 June 2022, on local content in oil and gas activities (see also 1.4 Principal Hydrocarbon Law(s) and Regulations, 3.7 Local Content Requirements: Midstream/Downstream and 4.1 Foreign Investment Rules Applicable to Domestic Investments in Hydrocarbons on local content). This law provides the rules of application of the local content law. All notifications made must be in writing and in French (Law No 2022-408 of 13 June 2022).
An Ivorian company is defined as an Ivorian business, 51% of which is held by an individual or a legal entity itself controlled by Ivorian citizens (Article 4). It provides criteria to evaluate local content by means of indexes. These indexes will be prescribed by the ministry in charge of hydrocarbons, and are defined as follows.
The Decree prescribes the way Ivorian personnel will be hired upstream and downstream. It provides the percentages for each stage both for upstream and downstream (Article 8); for example, 50% of Ivorian employees at the beginning of upstream activities and 75% for the beginning of downstream activities.
All hiring of non-Ivorian workers will be done by exemption following certain conditions and procedures (Articles 9–18). This exemption can be granted on a motivated application that includes the prescribed elements; for example, proof of publication of the call for candidates in the national mass media and of the absence of Ivorian candidates for the position, as well as a special training plan for Ivorian personnel to replace non-Ivorian staff.
This Decree also governs the procedure for awarding contracts and giving preference to Ivorian companies (Chapter V). Invitations to tender for the award of contracts for oil subcontracting, the provision of services or the supply of goods and services in oil and gas activities are open to all companies.
With the aim of transferring knowledge, oil companies, subcontractors, service providers and suppliers involved in oil and gas activities in the Republic of Côte d’Ivoire, other than Ivorian companies, must, within two years at the latest of starting their activities, conclude and finance partnership agreements with at least one Ivorian university or training institute. The conditions and processes are governed by Chapter VI of the Decree. This also governs local content plans and annual reports, controls and verifications.
The Decree also prescribes sanctions to be applied to those who do not abide by the indexes, as well as other conditions (Chapter VIII). Annexes provide lists of job positions and oil subcontracting, service provision and supply of goods and services activities both upstream and downstream.
In 2024, the government enacted multiple decrees and orders regarding local content:
A new digital platform for local content was also created this year by Order No 137/MMPE/DGH of 15 April 2024 on the creation and operation of the digital platform dedicated to local content in oil and gas activities in Côte d’Ivoire. This digital platform also makes it possible to dematerialise all the procedures for applying for or renewing authorisations, and to monitor and evaluate the state’s policy on local content in oil and gas activities in Côte d’Ivoire. Any oil company, oil subcontractor, service provider or supplier of goods and services for oil and gas activities, is required to register on the said digital platform dedicated to local content. Registration on the digital platform dedicated to local content is annual and subject to payment of a registration fee.
Regarding the digital platform, the following regulations have been enacted:
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houda@avocatshouda.com www.avocatshouda.com/enLegal and Regulatory Framework for Oil and Gas Development in Côte d’Ivoire: Between Contractual Stability and the Push for Reform
Côte d’Ivoire’s oil and gas sector has long stood as a pillar of contractual stability in West Africa, offering international investors a predictable legal environment rooted in well-established production-sharing contracts (PSCs). However, this stability is now being tested and transformed by a series of regulatory developments intended to promote local content, reinforce environmental compliance, and align the sector with the broader energy transition. These evolutions, while essential to national development goals, call for careful navigation by stakeholders seeking to do business in the country.
Contractual stability as a long-standing cornerstone
For over two decades, Côte d’Ivoire has relied on PSCs to structure relationships between the state and oil companies. These PSCs are based on a model agreement, offering a clear framework for exploration, development and production phases. The foundation of this regime remains Law No 96-669 of 29 August 1996, known as the “Petroleum Code”.
These contracts typically include stabilisation clauses protecting the economic equilibrium of a project against adverse changes in law or taxation. This has been particularly instrumental in securing large-scale offshore developments, such as the Baleine and Calao fields.
Côte d’Ivoire’s PSC model provides:
This predictable environment has historically enabled the country to attract major international oil companies, even in periods of geopolitical or market instability.
In this legal ecosystem, it is worth highlighting that the national oil company, PETROCI, plays a central role in exploration and production activities. Although initially established as a state-owned company under Law No 97-519 of 4 September 1997, PETROCI has been converted into a public financial participation company (société à participation financière publique) by Decree No 2001-580 of 12 September 2001, subject to partial privatisation. As such, PETROCI remains governed by both public and private law principles and is subject to the common business law framework of the OHADA Uniform Acts, in addition to the national hydrocarbon legislation.
While the core provisions of the Petroleum Code stem from Law No 96-669 of 29 August 1996, this framework was updated by Ordinance No 2012-369 of 18 April 2012, which amended Articles 1, 18, 37, 53 and 82. The ordinance introduced key reforms aimed at strengthening the national strategy for exploration and production, reinforcing transparency in extractive industries, enhancing environmental protection and site rehabilitation (particularly for abandoned sites), and supporting capacity building in the petroleum sector. These adjustments reinforced the robustness of the PSC model while providing greater regulatory clarity in response to evolving sector needs.
Beyond the legislative framework, Côte d’Ivoire also wishes to reinforce contract enforcement mechanisms. The recognition of international arbitration awards is guaranteed under the 1958 New York Convention, to which Côte d’Ivoire has been a party since 1991. In practice, petroleum contracts often designate arbitration under ICSID or ICC rules, seated in Paris or Abidjan. This offers reassurance to international investors seeking effective dispute resolution mechanisms in case of contractual breaches or regulatory disputes.
The role of national actors and dual regulatory regimes
Côte d’Ivoire’s oil and gas sector is not only shaped by its legislative environment but also by the institutional weight of national actors such as PETROCI. As the national oil company, PETROCI operates under a dual regime, combining the rules applicable to state-owned enterprises and those governing public-private partnership entities.
While initially structured as a wholly state-owned company, PETROCI was transformed in 2001 into a company with public financial participation, paving the way for partial privatisation and compliance with private company law principles. Despite its public ownership, PETROCI remains bound by the OHADA Uniform Acts, particularly those relating to commercial companies and general obligations, ensuring transparency and a level playing field for private operators engaged in joint ventures or subcontracting agreements with PETROCI.
Moreover, its upstream activities fall squarely under the provisions of the 1996 Petroleum Code and its implementing decrees, notably Decree No 96-733 of 19 September 1996 on general application modalities and Decree No 92-470 of 30 July 1992 on fraud and safety compliance. These texts reinforce both regulatory oversight and operational discipline in the sector.
The rise of local content and its regulatory architecture
In recent years, Côte d’Ivoire has shifted from a purely contractual model to a more regulated sector, with a strong emphasis on local content. This shift was formalised by Law No 2022-408 of 13 June 2022 on local content in oil and gas activities, and its implementing Decree No 2023-441 of 24 May 2023.
The objectives of the local content legislation are clear: foster employment for Ivorian nationals, encourage the use of local goods and services, and promote knowledge transfer and skill development.
Key obligations under the new framework include:
The scope of the local content regime also includes capacity-building requirements. Companies must not only hire and subcontract locally, but also invest in the training and upskilling of Ivorian nationals. These initiatives may take the form of inhouse training programmes, university partnerships, or contributions to national petroleum training funds. While these obligations may increase upfront compliance costs, they are designed to ensure the long-term integration of Ivorian talent into the value chain.
To ensure effective implementation, a digital platform was launched by the DGH in 2024 (Circular No 0007/MMPE/DGH of 28 June 2024). This platform enables operators and service providers to:
The platform also facilitates transparency by publishing tenders, approved suppliers, and administrative penalties for non-compliance.
Regulatory tensions: local content v contractual guarantees
One of the growing tensions in the Ivorian legal landscape lies in the interaction between stabilisation clauses in PSCs and the evolving regulatory framework. While PSCs grant legal predictability to investors, the local content law imposes obligations that may increase costs or alter project timelines.
The law explicitly requires open tenders above certain thresholds (eg, XAF10 million for services in exploration). It also restricts the use of non-Ivorian personnel for several critical roles, such as legal, accounting and IT functions, which must be filled by nationals as per an official job list annexed to the 2023 Decree.
The Ivorian government has sought to manage this tension by introducing a derogation mechanism for non-Ivorian hires and partnerships. However, access to these derogations is conditional on the company meeting key local staff indices and demonstrating genuine efforts to localise expertise.
For investors, this means that while their contracts may be protected under PSCs, operational compliance increasingly depends on adapting to a more prescriptive and monitored framework.
Environmental and social impact obligations
Another significant trend is the strengthening of environmental oversight in oil and gas operations. In line with global best practices and financing requirements from multilateral institutions, Côte d’Ivoire is gradually enhancing its environmental and social impact assessment (ESIA) obligations.
While ESIA procedures have long existed under the Environment Code, recent government statements suggest upcoming reforms to:
Companies operating in sensitive coastal or marine zones will be subject to heightened scrutiny. Some operators have already begun to adopt international ESG (environmental, social and governance) standards voluntarily, anticipating tighter local rules.
The government has also encouraged public-private dialogue on environmental sustainability through the Salon International des Ressources Extractives et Énergétiques (SIREXE), a biannual forum launched in 2024 in Abidjan to strengthen stakeholder co-ordination.
In addition to new obligations on emissions and biodiversity, operators are increasingly expected to develop Environmental and Social Management Plans (ESMPs) in line with International Finance Corporation (IFC) performance standards. These plans must cover not only operational risks but also community engagement, land acquisition, and stakeholder grievance mechanisms. Compliance is monitored by the National Environment Agency (l’Agence Nationale de l'Environnement or ANDE), which is being strengthened with new digital tools and additional technical personnel.
In parallel, Côte d’Ivoire is increasingly mobilising international financing to support its energy transition agenda. In 2023, the country secured a EUR15 million grant from the European Union under the Green Energy Production Support Programme (Programme d’Appui à la Production d’Énergies Vertes or PAPEV programme) to promote investment in renewable energy infrastructure and off-grid electrification. The overarching national objective is to raise the share of renewables in the electricity mix to 45% by 2030, as stated in the Nationally Determined Contributions (NDCs) under the Paris Agreement.
These developments signal a shift towards a more integrated approach to energy policy, where environmental, social and climate objectives are increasingly reflected in the regulation of oil and gas activities.
Preparing for the energy transition: gas and beyond
The growing importance of gas in Côte d’Ivoire’s energy mix is another key driver of regulatory reform. The Baleine and Calao fields, rich in natural gas reserves, are central to the state’s strategy to power industrialisation and support electricity exports in the region.
To this end, the government is preparing new rules to facilitate gas-to-power projects and hybrid models integrating renewables. Anticipated reforms include:
Additionally, a cross-ministerial working group has been established to harmonise regulations between hydrocarbons and renewable energy sectors, ensuring legal certainty for future investors.
Furthermore, the government has launched consultations for the adoption of a new Renewable Energy Code, expected to create a specific licensing regime for independent power producers (IPPs) using solar, biomass and hybrid solutions. These initiatives aim to ensure better integration between traditional hydrocarbons and cleaner technologies, while positioning Côte d’Ivoire as a regional leader in energy transition financing and policy innovation.
Institutional strengthening and governance
The transformation of the sector has also led to increased institutional oversight. The DGH has significantly modernised its operations by:
These initiatives are supported by a wider national agenda to strengthen public governance, foster resilience, and promote green growth. In April 2025, the IMF concluded a technical agreement with Côte d’Ivoire under its Resilience and Sustainability Facility, unlocking a new disbursement of USD740 million to support structural and climate-related reforms. This includes measures to:
In parallel, the Ministry of Mines, Petroleum and Energy is working on a revision of the 1996 Petroleum Code to incorporate these governance priorities, as well as updated obligations related to local content, ESG compliance, and energy diversification.
The revision process of the Petroleum Code is expected to be participatory, involving consultation with industry stakeholders, civil society, and international development partners. One of the key objectives is to enhance alignment with global ESG reporting standards such as the Task Force on Climate-related Financial Disclosures (TCFD) and the Extractive Industries Transparency Initiative (EITI), to which Côte d’Ivoire has adhered since 2008.
These institutional developments reflect a dual objective: preserving investor confidence through robust legal frameworks while promoting long-term sustainability and inclusive growth in the energy sector.
Conclusion: preserving confidence amid regulatory change
Côte d’Ivoire’s oil and gas sector remains a dynamic and attractive destination for international investors. Its robust PSC model continues to offer contractual stability, while recent reforms demonstrate the country’s commitment to sustainable, inclusive and modernised energy development.
The co-existence of stability and reform creates both opportunities and challenges. Investors must now operate within a dual logic:
Navigating this evolving environment requires proactive legal and regulatory advice, strategic partnerships with local stakeholders, and a clear understanding of the government’s policy priorities.
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