Trinidad and Tobago is one of the clearest examples of a country whose modern economy has been built around natural gas. Oil shaped the country’s earlier energy history, but natural gas became the foundation for LNG exports, petrochemicals, industrial activity, and electricity generation. The result is a small Caribbean state with an energy role much larger than its population or land area would suggest.
The country’s gas sector is not only about producing fuel. It supports Atlantic LNG, ammonia plants, methanol facilities, power generation, and industrial estates such as Point Lisas. The Ministry of Energy and Energy Industries states that natural gas is used for LNG, petrochemical manufacturing, metals refining, heavy industry, and electricity generation.
That makes Trinidad and Tobago different from many gas producers. Its challenge is not only finding markets for gas exports. It must allocate limited gas among LNG, petrochemicals, power plants, and industrial users, all while maintaining enough upstream investment to offset decline.
A Gas-Based Export Model Built Around LNG and Petrochemicals
Trinidad and Tobago’s gas economy developed around two major export channels: liquefied natural gas and gas-based petrochemicals. Atlantic LNG gave the country a major position in global LNG trade, while ammonia and methanol production turned natural gas into higher-value industrial exports.
This model created a strong link between upstream gas production and downstream industry. When gas supply is strong, LNG trains and petrochemical plants can run at higher utilization. When feedgas is short, production falls, plants operate below capacity, and export earnings are affected.
The Ministry of Energy and Energy Industries describes LNG and petrochemicals as central parts of the country’s gas business, with natural gas used as both feedstock and fuel. It notes that domestic gas sales have historically gone to ammonia manufacturing, methanol manufacturing, power generation, and other heavy industries.
Trinidad and Tobago’s ammonia industry remains especially important. A 2025 study reported that ammonia production consumed approximately 17% of the country’s total natural gas supply in 2023.
This structure gives the country a sophisticated gas economy, but it also creates pressure. LNG exporters, petrochemical producers, and domestic power users all depend on the same upstream supply base. When production declines, the economic effects spread across several sectors at once.
Feedgas Shortages Have Become the Defining Constraint
The central problem in Trinidad and Tobago’s natural gas sector is not a lack of downstream capacity. It is the shortage of feedgas needed to fully supply that capacity. This has affected LNG output, petrochemical production, and the country’s ability to maintain its historical export position.
Reuters reported in May 2026 that Atlantic LNG shut its Train 4 processing unit for planned maintenance, temporarily reducing capacity. The report also noted that the facility has faced ongoing struggles related to declining domestic natural gas supplies and that Atlantic LNG permanently closed its smallest unit, Train 1, in 2025.
The feedgas issue is not temporary. Trinidad and Tobago has mature producing fields, and new upstream projects are needed to replace decline. Without enough new gas, the country risks underusing expensive infrastructure that was built for a larger supply base.
EnergyNow reported that first-quarter 2025 data showed a 5.9% year-on-year reduction in natural gas production, while petrochemical performance was mixed: ammonia and urea increased, but methanol output declined sharply.
That pattern shows why gas supply is a national economic issue. A decline in production is not just an upstream statistic. It affects LNG cargoes, petrochemical output, port activity, foreign exchange earnings, government revenue, and industrial employment.
New Offshore Projects Are Critical to Stabilizing Supply
Trinidad and Tobago’s natural gas future depends heavily on new offshore developments. The country needs additional gas to maintain LNG exports and downstream petrochemical production. Several projects are intended to slow or reverse the decline.
BP’s Cypre project is one of the key near-term developments. Reuters reported that bpTT began production from Cypre in April 2025 and that the project is expected to deliver around 45,000 barrels of oil equivalent per day at peak, equal to about 250 million standard cubic feet of gas.
Shell’s Manatee project is another major development. Reuters reported that Shell took a final investment decision in 2024 to develop the Manatee gas field offshore Trinidad. The field holds about 2.7 trillion cubic feet of natural gas and is expected to produce more than 600 million cubic feet per day at peak, with first gas expected in 2027.
These projects are important because they are tied directly to Trinidad and Tobago’s downstream survival. New gas can help supply Atlantic LNG, petrochemical plants, and domestic users. It can also improve investor confidence in a sector that has been constrained by underutilized infrastructure.
The question is whether new projects arrive quickly enough and at sufficient scale. Trinidad and Tobago does not need gas only for future growth. It needs gas to support existing industrial assets.
Cross-Border Gas Adds Opportunity and Political Complexity
Trinidad and Tobago’s location near Venezuela creates both opportunity and complication. Some gas resources straddle maritime boundaries or depend on cooperation involving Venezuela, international oil companies, and sanctions policy. These resources could help Trinidad and Tobago’s gas balance, but they are not simple commercial developments.
Reuters reported in February 2026 that BP was seeking a U.S. Office of Foreign Assets Control license for the Manakin-Cocuina gas field, which spans the Venezuela-Trinidad maritime border. The field is part of a broader effort to supply gas to Trinidad for LNG export, but U.S. sanctions on Venezuela’s PDVSA create legal and political hurdles.
Shell’s Manatee project is also linked to the wider Loran-Manatee field that crosses the Trinidad-Venezuela maritime boundary. Reuters reported that Trinidad and Venezuela reached an agreement allowing each country to independently develop its respective share.
Cross-border gas could be highly valuable because Trinidad and Tobago already has downstream infrastructure. Gas from nearby offshore resources can be monetized through LNG and petrochemicals more easily than in countries that must build an entire gas value chain from scratch. The limiting factor is political permission, legal certainty, and the ability to coordinate development across borders.
Electricity Depends Almost Entirely on Gas
Natural gas is also central to Trinidad and Tobago’s domestic electricity system. The country’s power generation has long relied on gas-fired plants, which benefit from local fuel supply and an established industrial gas network.
This gives Trinidad and Tobago relatively direct control over its power fuel compared with countries that import LNG or fuel oil. However, it also means that domestic electricity is tied to the same gas-supply challenge facing LNG and petrochemicals. Power generation may not consume as much gas as export-oriented industries, but it remains a priority use because electricity reliability affects households, businesses, and public services.
The country’s energy system therefore faces an allocation issue. Export industries generate foreign exchange and government revenue, while domestic power generation supports the national economy. When gas is abundant, the system can serve both priorities. When supply is tight, policymakers and the National Gas Company must manage tradeoffs among LNG, petrochemicals, power, and industrial users.
Trinidad and Tobago’s Gas Outlook Is a Race Between Decline and New Supply
Trinidad and Tobago’s natural gas sector is not starting from weakness. It has experienced operators, established offshore production, LNG infrastructure, petrochemical plants, ports, and a long history of gas commercialization. Those are major advantages.
The problem is that the country’s infrastructure was built for a stronger feedgas environment than it has had in recent years. If new projects such as Cypre and Manatee perform as expected, they can help stabilize supply and improve utilization across LNG and petrochemicals. If development is delayed or production disappoints, the country could continue facing underused industrial capacity and pressure on export earnings.
The next phase of Trinidad and Tobago’s gas economy will depend on upstream delivery, cross-border resource development, contract stability, and the ability to keep downstream plants supplied. Natural gas remains the country’s central energy asset, but its value now depends on whether new production can arrive fast enough to protect the industrial system built around it.