Trinidad and Tobago (T&T) has a mature petroleum industry. The first oil well was drilled in 1857 in the vicinity of T&T's Pitch Lake in La Brea. The first successful well was drilled in 1866 in Aripero, and commercial oil production is recorded as having begun in 1902 near the Pitch Lake.2 Until the mid-1950s, petroleum exploration was land-based. In 1954, exploration moved offshore into the East Coast marine areas resulting in significant discoveries.3 Marine exploration now extends into the deep.
Petroleum rights in T&T are owned by the state (public petroleum rights) or by private persons (private petroleum rights). Prior to 30 January 1902, the original grants of real estate by the state included all sub-surface rights not expressly reserved by the state. This effectively vested private persons with petroleum rights. Thereafter the state reserved all sub-surface rights. Public petroleum rights are vested in the state and exercisable by the President. They exist in state lands, private lands where the sub-surface rights have been reserved to the state and all marine areas. It is not uncommon for private petroleum rights owners to dispose of their surface rights and retain the subsurface petroleum rights.
T&T is the most industrialised nation in the Caribbean and is one of the wealthiest because of its oil and gas reserves. The exploitation of hydrocarbons dominates its economy. The availability of historically inexpensive natural gas as feedstock has facilitated a well-developed petrochemicals sector. T&T is one of the world's largest exporters of ammonia with 11 ammonia plants, seven methanol plants with an eighth under construction, two urea plants, nitric acid, ammonium nitrate, urea ammonium nitrate, melamine plants and a dimethyl ether plant under construction. It is one of the largest exporters of liquefied natural gas in the world operating a four-train liquefaction facility. In late 2018, T&T's last functioning oil refinery was shut down by the state-owned Petroleum Company of Trinidad and Tobago Limited (Petrotrin) following a government decision to restructure Petrotrin's refining and exploration and production business.
Owing to a lapse in exploration activity (which resulted in a decline in reserves) and falling oil prices, the T&T economy has faced hardships in recent years. Gas shortages also affected the petrochemical sector. 2019 continues to show promise with global oil prices demonstrating some signs of strengthening, additional natural gas discoveries, bettered supplies of natural gas to the downstream as well as confirmed commitments for investment by the upstream.
II LEGAL AND REGULATORY FRAMEWORK
i Domestic oil and gas legislation
The petroleum industry is governed primarily by the Petroleum Act (the Act) and the Petroleum Regulations (the Regulations). Together they address the grant of exploration and production licences (E&P Licences) and production sharing contracts (PSCs) for upstream onshore or offshore exploration and production and several other petroleum operations.
The term 'petroleum operations' is widely defined under the Act, it includes petroleum exploration and production but excludes petroleum mining or extraction from shales, tar sands, asphalts or like deposits. The Act and the Regulations do not address specific gas-related issues; nor do they address unconventional petroleum exploration (such as fracking or shale gas). As a result, specific gas related issues are normally dealt with by more detailed provisions included in the relevant PSC or E&P Licence.
It is an offence under the Act for petroleum operations (whether relating to public or private petroleum rights) to be conducted without a licence. The fine for failing to obtain a licence is currently TT$500,000, and in the case of a continuing offence, TT$50,000 for every day in which the offence continues.
The Minister of Energy and Energy Industries (the Minister) is the primary regulator of the petroleum industry and performs his or her functions through the Ministry of Energy and Energy Industries (MEEI). Petroleum operations also trigger other general regulatory requirements overseen by other regulators, for example, health, safety and environment (HSE) regulation.
The Minister, subject to the directions of the T&T Cabinet, is charged with the general administration of the Act (which together with the Regulations govern his powers and duties). He is responsible for, inter alia, regulating the petroleum industry, enforcing the provisions of the Act/Regulations, granting, revoking, varying and enforcing concessions and granting ancillary rights to concession holders.
T&T is a member/signatory to several trade and investment treaties the most notable of which is the Caribbean Community (CARICOM). CARICOM's main pillars are to promote economic integration, foreign policy coordination, human and social development and security within the Caribbean.4 CARICOM has entered into several Free Trade Agreements (FTAs) on behalf of its members with third states, following which T&T implemented these FTAs into its domestic legislation.
T&T has also entered into Bilateral Investment Treaties (BITs) with several countries designed to encourage favourable conditions for investors of those countries to make investments in T&T.5 These BITs also require each party to grant investors of the other party terms no less favourable than those which it grants to investors of any third state in similar circumstances.
Many of these BITs are not incorporated into T&T's domestic laws, and, therefore, T&T courts will not enforce them. BITs however typically specify dispute resolution mechanisms including international arbitration. Petroleum investments would normally be considered an 'investment' within a BIT, and if these investments were negatively affected by the government of Trinidad and Tobago, the aggrieved foreign investor may seek to enforce its rights (or have its country do so) under the relevant BIT through the specified dispute resolution procedure.
The Convention on the Recognition and Enforcement of Foreign Arbitral Awards, 1958 was incorporated into T&T's domestic law by the Arbitration (Foreign Arbitral Awards) Act. The Convention relating to the International Centre for Settlement of Investment Disputes was also incorporated into T&T's domestic law by the Investment Disputes Awards (Enforcement) Act. These statutes are designed to accelerate the enforcement process for arbitral awards in comparison to the slower procedure required at common law.
T&T has concluded several double taxation treaties that either reduce or completely mitigate the taxes imposed by the home treaty country on residents of the other treaty country.6
Upstream concessions are granted by the state under: (1) PSCs; (2) public E&P Licences (which relate to public petroleum rights); (3) private E&P Licences (which relate to private petroleum rights); and (4) exploration licences. Where a concession relates to acreage that covers both public and private petroleum rights, the MEEI typically issues a single public E&P Licence. The concessions at (1) to (3) will include a minimum exploration work programme (MEWP), but its extent will vary between concessions. Rights in marine areas are now managed primarily by PSCs but a fair amount of marine acreage remains subject to public E&P Licences.
An E&P Licence confers the exclusive right to prospect for and dispose of petroleum in the licensed area. PSCs give similar exclusive rights in respect of a defined contract area. Neither confer ownership of any petroleum in strata. Exploration licences give a non-exclusive right to explore within the licensed area and are now seldomly issued.
Since the State does not own private petroleum rights, prior to any application to the Minister for a private E&P Licence the applicant must obtain the consent of the title holder (generally through an oil mining lease) and evidence thereof must be supplied to the Minister for verification.
Applications for E&P Licences must be made in writing to the Minister who then publishes them in the Gazette and at least one local daily newspaper to allow opportunity for public objection. An application fee of TT$500 is payable. If the application is in order, the Minister will decide the application after considering any objections.
Public petroleum rights are exercisable by the President but the Minister is responsible for determining the areas to be made available for petroleum operations. The President in his or her discretion can, however, select an area to be subject to a competitive bidding process. The Minister must then publish a Competitive Bidding Order (CBO) in the Gazette and at least one local daily newspaper outlining, inter alia, the bid procedure, the available blocks and the bid assessment criteria.
Competitive bid rounds are standard for marine blocks. This process was also utilised in 2013 for certain onshore blocks. Successful bidders are selected by the Minister after analysis of the bids in accordance with the evaluation criteria (and the MEEI's internal benchmarks) and in consultation with the Minister of Finance. PSCs have occasionally been awarded by the Minister out of round, where there were no acceptable bids and the MEEI requested a bidder (seemingly the bidder closest to the internal MEEI benchmark) to submit a revised bid.
Public E&P Licences are granted for the initial term of six years, and where a commercial discovery is made they can be renewed for a maximum term of 25 years, with further successive five-year extensions. Extensions of the initial term are possible in the absence of a commercial discovery where the Minister considers that continued exploration will enhance the identification or evaluation of reserves and the extension is in the public interest.
In addition to production royalties, E&P Licences tend to incorporate a combination of the following fiscal obligations including performance guarantees for the agreed MEWP, treasury deposit in cash, payment of all other applicable duties, taxes, charges or fees, annual surface rents, minimum payments for the licensed area, an escrow account for pollution remediation and abandonment of facilities and wells, annual training contributions for nationals, annual research and development payments, annual scholarships, signature bonus, technical equipment bonus, environmental bonus and production bonus. Relinquishment of portions of the licensed area is also required by the Regulations. Licensees are liable, without limitation for all damage caused as a result of their negligent actions or their subcontractors and are required to indemnify the Minister without limitation for resulting third-party claims brought against him or her.
Private E&P Licences are granted for a term of 20 years and subject to renewals for successive periods of 20 years. Private Licensees are not required under the Regulations to provide bonds or guarantees. The Minister, however, has included these obligations in private E&P Licences in the past. Production royalties are not payable to the Minister since the petroleum rights are privately owned. Private E&P Licences, in comparison to the public E&P Licences, tend to contain less onerous fiscal terms. The obligations normally include the payment of all applicable taxes, duties, charges and rents, a bond or guarantee for the abandonment of wells, escrow account for pollution remediation and abandonment of wells, annual contributions for training of nationals and additional monetary deposits. Otherwise, they are roughly similar to public E&P Licences.
PSCs have an initial exploration term and successive extensions similar to public E&P Licences. However the initial term is usually divided into shorter phases and proceeding from one phase into the other is dependent on satisfactory performance of the agreed MEWP for each phase. PSCs typically provide for specific guarantees with respect to the MEWP and work obligations undertaken in subsequent phases, a general third party or parent company guarantee for the breach of any obligation under the PSC, and a letter of undertaking from a financially, technically and legally competent parent company that it will provide the contractor with the technical and financial resources as are required to meet its obligations under the PSC. Specific relinquishment provisions are also provided for in each PSC. The exact percentage to be relinquished and the timelines for such relinquishment vary, and the Minister has the discretion to vary these requirements. Cash flows generated under PSCs come from the sale of petroleum by the contractor and are distributed between the Minister and the contractor in accordance with agreed cost recovery petroleum and profit petroleum splits, which are typically biddable. Cost recovery is not applicable to all revenues and defined accounting rules and procedures (with rights of audit) are specified in PSCs.
The majority of PSCs are 'tax paid' contracts where the Minister undertakes to pay the contractor's taxes and other payments out of his or her share of profit petroleum and gives an indemnity from all other payments to and levies by the Treasury or the government (including royalties) whether or not existing at the date of the PSC, save for specified financial and tax obligations. Consequently, the tax regime applicable to upstream operations ought not to affect contractors directly. The tax obligations directly payable by the contractor typically relate to payroll taxes, stamp, import and excise duties and in some cases withholding tax. The Minister's contractual undertaking or obligation to pay the contractor's taxes is not fully supported by formal legislation and in those cases that undertaking or obligation to pay under the PSCs' 'tax paid' provisions arguably does not strip the Revenue of its entitlement to pursue the contractor, though this has not, as far as we are aware, ever happened in practice.
Termination provisions in E&P Licences and PSCs can be triggered as a result of breach or pursuant to the normal expiry of the term or via voluntary relinquishment prior to its expiration. Items of material breach prompting a right of termination in E&P Licences and PSCs include failure to perform the MEWP and other work obligations and failure to obtain the prior consent of the Minister to an assignment. Termination on this basis usually first requires the giving of notice and the opportunity to remedy. E&P Licences may also provide for ministerial termination where the licensee fails to make any required payments, fails to pay any arbitral awards, becomes bankrupt or insolvent or makes a wilful misrepresentation in its E&P Licence application.
IV PRODUCTION RESTRICTIONS
Subject to any contrary requirements in the E&P Licence, a licensee has a general right to export petroleum. However, the President reserves the right under the Act to take possession of production and in times of emergency to require further production from the licensee. The Minister can also direct producing licensees to have their production refined locally though this is no longer practicable with the close of T&T's last oil refinery in 2018. PSCs tend to address the issue of exportation in more detail, and the contractor's right to export natural gas is more restricted. Marketing arrangements for any natural gas are subject to the Minister's approval, and the contractor must demonstrate to the Minister that the price of the natural gas at the measurement point represents the fair market value obtainable. Any proposed export project for natural gas is subject to the discretion of the Minister. Apart from the restrictions on natural gas exportation, the contractor has a general right to export petroleum subject to the government's right of requisition in times of war or national emergency with compensation.
V ASSIGNMENTS OF INTERESTS
The Minister's prior written consent must be obtained for any assignment or transfer of an interest under an E&P Licence and for the issue of a sublicence by a licensee. Failure to obtain consent renders an assignment or transfer null and void (at least against the Minister) and exposes the E&P Licence to forfeiture by the Minister. A written application for consent must be made to the Minister with a fee of TT$100, and provision of the same information in respect of the proposed assignee or transferee as required for an application for the E&P Licence. This restriction is not, however, sufficiently wide to prohibit transfers by virtue of changes in control.
Historically PSCs tended only to restrict the actual assignment of the PSC or an interest therein, and contractors under PSCs have often disposed of their interests by way of a sale of shares in the special purpose company used as the contractor entity to enter into the relevant PSC. In recent years, the MEEI has expanded the definition of the term 'transfer' under PSCs in an effort to ensure that disposals of the special purpose contractor entity by a sale of shares or a change in control will qualify as a transfer. We have not seen any E&P Licences incorporating similar language. Under modern PSCs, the Minister now reserves the right to impose a transfer fee upon the transfer of the PSC (or an interest therein) based on the value of the transfer consideration. This transfer fee will not apply if stamp duty has been paid on the transfer.
Apart from certain taxes applicable to all companies, petroleum companies involved in production operations are subject to the following separate taxation regime.
Petroleum Profits Tax (PPT) is payable at a rate of 50 per cent (35 per cent for deep water operations) and is the petroleum equivalent to corporation tax (which applies to other companies). Outgoings and expenses (other than capital allowances) are determined and deducted in accordance with normal income tax principles together with deductions for supplemental petroleum tax (SPT), petroleum impost (Impost), petroleum production levy (PPL) and royalty (each as explained below) in order to determine chargeable income.
SPT is charged on gross income from the disposal of crude oil. The only deduction permitted is royalty (including overriding royalty). SPT becomes payable when crude prices exceed specific thresholds on a sliding scale increasing with the price of crude and depending on the type of licence or PSC held.
Impost is to be paid by every E&P Licensee in respect of petroleum won and saved at rates per barrel of crude oil and per mscf natural gas as specified by the Minister. The applicable rates are published annually. The last rate published (for 2017) was 47.1533200 cents per barrel of crude and 8.1298828 cents per mcf of natural gas. The 2018 rates will be published in late 2019.
PPL is levied on every producer (the levy is pro-rated in accordance with a producer's percentage of the country's total production) in respect of any production business with a daily average production of over 3,500 barrels. The total levy is used to pay a subsidy to traders in the petroleum marketing business, which in turn supports a fuel subsidy for T&T consumers. The maximum charge that can be levied is 4 per cent of gross income from the production of crude oil. The subsidy is being gradually phased out.
Effective from 1 January 2018, royalties are payable by Public E&P Licensees and PSC contractors at a rate of 12.5 per cent on the net volume of crude oil and natural gas won and saved from the licensed or contract area at fair market value. However, arguably the existing tax paid or tax indemnified PSCs (which typically cover royalties) will prevail, and the Minister will continue to make these payments from his or her share of profit petroleum. However the terms of each PSC will need to be considered, and it is possible that any financial hardships experienced upstream will be passed down to the downstream industry.
Unemployment levy (UL) is payable at the rate of 5 per cent of taxable profits of a person for a current financial year. Unlike PPT, no relief is given for losses brought forward.
Though under general tax law, a contractor is liable for T&T tax, depending on the nature of the PSC, the Minister contracts to pay the contractor's liability for PPT, SPT, UL, PPL, royalties, Impost and green fund levy (GFL). In addition there are various accelerated capital and other allowances and incentives available under the Petroleum Taxes Act and the Income Tax (In Aid of Industry) Act.
Taxes of general application include the following:
- GFL (0.3 per cent of gross income);
- VAT (at 12.5 per cent on imports and T&T based commercial supplies save where zero-rated or exempt);
- customs duties (at varying rates on imports according to the common external tariff);
- withholding tax on distributions and named species of payment to non-residents (at 5 per cent, 10 per cent and 15 per cent);
- PAYE, national insurance and health surcharge on emolument income paid to employees (the employer is responsible for deducting and remitting same to the Revenue);
- stamp duty (levied at varying specified statutory rates on various instruments); and
- property tax (this is a new tax and implementation is in process; it is payable on all land on an annual rental value basis (less deductions and allowances) at varying rates depending on whether the land is agricultural (1 per cent), residential (3 per cent), commercial (5 per cent) or industrial (6 per cent housed machinery and 3 per cent machinery not housed)).
VII ENVIRONMENTAL IMPACT AND DECOMMISSIONING
The Act and Regulations contain general provisions that are intended to protect the environment. The Regulations place obligations on Licensees to execute operations so as not to unreasonably interfere with other activities in the area and to take care to avoid pollution of marine areas. Licensees are also required to take all reasonable precautions and safety measures to ensure that water resources are not damaged or contaminated by operations. Where a Licensee fails to adopt appropriate measures for safety, health and welfare and for pollution prevention, the Minister may (upon the expiry of a default notice, where no emergency exists) execute such works and recover the costs and expenses from the Licensee. The MEEI also inspects and monitors environmental quality and equipment used in areas with energy related facilities. Recently the liability for proper facility abandonment and for pollution remediation has become a matter of increasing concern, particularly for marine areas.7 This has resulted in express provisions concerning environmental remediation being incorporated into concessions. These usually involve the Contractor/Licensee making an environmental plan and setting up escrow accounts for the pollution remediation and the abandonment of facilities. The MEEI also normally requires Contractors/Licensees to undertake to comply with its National Oil Spill Contingency Plan. The Petroleum (Pollution Compensation) Regulations deal with onshore spills and a compensation process for redress where damage is caused to property, crops and other agricultural holdings.
The Environmental Management Act (the EM Act) together with its subsidiary legislation is the primary environmental law regulating upstream operations. The EM Act is focused on the implementation of laws and policies and a framework for the protection, conservation, use and management of the environment. It establishes the Environmental Management Authority (EMA),8 the principal environmental regulator with wide discretion over the kinds of action that it may take in the event of a spill of pollutants including petroleum. The Environmental Commission, a superior court of record sitting on appeals from EMA decisions is also established under the EM Act. The EM Act regulates the release of various pollutants and exploration, production, refining and decommissioning operations. The EM Act's subsidiary legislation most pertinent to upstream operations include the Certificate of Environmental Clearance (CEC) Rules and the CEC (Designated Activities) Order under which CECs for various upstream activities (including exploration, production and decommissioning) are required before they can be started. The CEC process will also often require environmental impact assessments and a public consultation process. Other relevant rules include the Water Pollution Rules, Air Pollution Rules and Noise Pollution Rules, which address approvals, registrations and permits for operations causing these types of pollution.
The Occupational Safety and Health Act (the OSH Act) applies to all 'industrial establishments'; this term includes vessels, offshore installations and any movable structure. The OSH Act is designed to revise and extend the law regarding the safety, health and welfare of persons at work and imposes duties and obligations on upstream operators to the extent that they employ persons working at industrial establishments. The Occupational Safety and Health Authority (OSHA) is charged with enforcing the OSH Act, and inspectors have the power to enter and inspect premises for the purposes of ensuring compliance. Apart from penalties for various offences, OSHA has the power to issue 'prohibition notices' that prohibit the use of premises until danger is removed and 'improvement notices' that require improvements to facilities in order to remove danger. Actions under the OSH Act are heard by the Industrial Court, which is a superior court of record established under the Industrial Relations Act. There are certain general duties owed by an employer to, among other things, ensure the safety, health and welfare at work of his employees, so far as is 'reasonably practicable'. Other specific duties pertain to protocols where hazardous chemicals or substances are present and to the actions to be taken in the event of accidents and occupational diseases. Occupiers (those in ultimate control of a facility) also owe duties, many of which are owed to employees. These include the formulation of a general policy on health and safety and the preparation of various emergency plans, the appointment of a safety practitioner and a duty to ensure that no unsafe structures exist. In addition, an occupier is responsible for managing the environment and protecting the public from dangers created by the operations of the industrial establishment.
VIII FOREIGN INVESTMENT CONSIDERATIONS
Non-resident companies wishing to engage in upstream operations must establish a local place of business, branch or agency. Once a non-resident establishes a place of business in T&T it must formally register itself as an External Company within 14 days pursuant to the Companies Act by filing the appropriate Form 20 and supporting corporate instruments and declarations with the Registrar of Companies.
Non-resident companies can also incorporate either private limited or unlimited liability subsidiary companies. A name approval application must first be made which typically takes around five working days. Following receipt of the name approval, non-resident companies classified as 'foreign investors' under the Foreign Investment Act must prior to incorporation9 file an administrative notice with the Minister of Finance setting out specified particulars. Thereafter the relevant articles of incorporation, notices of directors, registered office and secretary are filed with the Registrar of Companies to effect the incorporation.
ii Capital, labour and content restrictions
There are no exchange controls on the negotiation of contracts, payment of obligations and holding of bank accounts in foreign currency. The Exchange and Control Act limits the purchase and sale of foreign currency to and by authorised dealers. There is no requirement for exchange control approval for foreign investments or the payments or repatriation of capital from T&T to a foreign country. However, T&T periodically experiences foreign currency shortages. The par value of the T&T dollar is floated against the US dollar and consequently against every other foreign currency.
Licensees are required under the Act to minimise employment of foreign personnel and train and seek employment of T&T nationals. The MEEI issued a Local Content & Local Participation Policy & Framework (the Local Content Policy) in 2004. It is very general. While it has not been passed into law, it is incorporated into PSCs and the more recent public E&P Licences.
PSC contractors undertake open-ended obligations to observe the Local Content Policy as modified from time to time together with specific obligations regarding local content including maximising the use of local goods and services, business, employment of T&T nationals, advertising, financing, evaluating and awarding all tenders in T&T (except where special permission from the Minister is obtained), imparting to nationals business and technology expertise in all areas of the energy sector and preparing and submitting periodic local content reports to the Minister.
Non-nationals may only engage in employment in T&T for a single period not exceeding 30 days every 12 months. Otherwise a work permit is obtained from the Ministry of National Security. The application is considered by the Work Permit Committee which consists of various members of the Ministry of National Security, the Ministry of Labour and Small Enterprise Development and the MEEI (among others).
T&T received a score of 41 out of 100 in Transparency International's 2018 Corruption Perceptions Index and ranked 78th out of 180 countries.10 The Prevention of Corruption Act (the Prevention Act) is the main corruption legislation. The terms 'bribe' or 'bribery' are not defined, but a variety of actions are prohibited that would be regarded as offering or giving a bribe and seeking or receiving a bribe. Public and private sectors are subject to the Prevention Act, and it provides for offences involving the corrupt offering, promising, giving, soliciting and receiving of gifts, loans, fees, rewards and advantages. 'Consideration' is defined as including any valuable consideration of any kind, and so small grease payments are also prohibited. The use of an agent or third party (innocent or otherwise) in the commission of an offence will not allow the offender to escape criminal liability. Punishments for offences under the Prevention Act include fines, penalties, imprisonment and other forms of chastisement.
Other legislation with anti-corruption ramifications include: (1) the Proceeds of Crime Act which requires, inter alia, the disclosure of information on the source of certain funds and obtaining certain business information from clients or business partners in specified transactions; and (2) the Integrity in Public Life Act, which, inter alia, regulates the acceptance of gifts by those in public office and pubic life and mandates the periodic disclosure of financial information by those in public office and public life to the Integrity Commission.
While confirmed cases of corruption in the petroleum sector are rare, in 2017 there was some speculation surrounding certain fake oil transactions involving Petrotrin and an upstream operator alleging discrepancies between the operator's actual oil production and delivery levels and purportedly inflated levels shown on invoices presented to and paid for by Petrotrin.
IX CURRENT DEVELOPMENTS
T&T's petrochemical industry has thrived over the years, but in prior years the industry faced some challenges due to gas supply shortages. These challenges appear to have been mitigated, at least in the short term, by the concerted efforts of the MEEI and the upstream operators. Recently, state-owned, The National Gas Company of Trinidad and Tobago Limited signed a term sheet with Shell Trinidad Limited for additional gas supplies.11
In November 2018, the MEEI launched a shallow water bid round, which closed on 20 May 2019.12 The six Shallow Water Blocks are located off the north, west and east coasts of Trinidad. Bidders were required to propose for all blocks, a 15 per cent carry for the state in the first six years of the exploration period.13 Successful bids are expected to be announced six months after the close of bidding.14
In 2018, the government announced its decision to restructure Petrotrin's operations. By virtue of the Miscellaneous Provisions (Heritage Petroleum, Paria Fuel Trading and Guaracara Refining Vesting) Act 2018, effective 1 December 2018, Petrotrin's assets were transferred to three affiliated companies. Heritage Petroleum Company Limited became vested with Petrotrin's exploration and production assets, Paria Fuel Trading Company Limited with terminalling assets and the Guaracara Refining Company Limited with refinery assets.
1 Jon Paul Mouttet is a senior partner in the commercial department, Lesley-Ann Marsang is an associate in the commercial department and Simonne Jaggernauth is an associate in the advocacy, litigation & ADR department at Fitzwilliam, Stone, Furness-Smith & Morgan.
3 History of Petroleum Exploration in Trinidad and Tobago, Search and Discovery Article #70231 (2016), K M Persad and C Archie.
7 In terms of general marine related legislation, the Continental Shelf Act makes it an offence where oil escapes into the sea in a designated area from a pipeline or otherwise (other than from a ship) as a result of any operations for the exploration of the seabed and subsoil or the exploitation of their natural resources and the Oil Pollution of Territorial Waters Act makes it an offence for a vessel to discharge oil into T&T waters. These statutes are, however, quite old with very small penalties and do not adequately address liability for marine related petroleum pollution. T&T is also a party to several international conventions that are specific to oil spills, but several of these have not been incorporated into domestic law.
9 This notice must also be filed prior to any share issuance by the company to a foreign investor. Consideration for such shares must also be paid for in an internationally traded currency through a licensed dealer of foreign exchange.
13 Clause 11(1)(d) of the Petroleum Regulations (Shallow Water Competitive Bidding) Order, 2018, as amended by the Petroleum Regulations (Shallow Water Competitive Bidding) (Amendment) Order, 2019.