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Trinidad & Tobago Ministry of Energy Report: More gas coming




By TT Guardian

Petroleumworld 07 30 2018

The Government has promised that the natural gas shortages experienced by the downstream companies will come to an end by 2021. It has based its projections on improved production from the upstream energy companies and on natural gas from Venezuela's Dragon Field.

A copy of a confidential Ministry of Energy report outlines in detail where that gas is going to come from and reveals some of the plans for increased production.

The report projects that this year natural gas production will average 3.79 billion cubic feet per day (bcf/d) in 2018. That will increase to 3.94 bcf/d next year, 4.05 bcf/d in 2020 and 4.14 bcf/d in 2021. It must be noted that the country's installed capacity is 4.2 bcf/d and part of the overall production of natural gas is re-injected in to lift more crude oil.

Of the increased production, 80 million standard cubic feet will come from the newest upstream producer, De Novo Energy. De Novo is part of the Proman Group which owns and operates several downstream plants on the Pint Lisas Industrial Estate, including CNC and Methanol Holdings Limited.

The report states: “The Iguana field will be developed from a platform with three producing wells and a maximum design capacity of 90 mmscf/d. The produced gas and liquids will be exported through a 42 km, 14 inch export pipeline to a dedicated gas processing unit where it will be processed to remove condensate.”

The Ministry of Energy report notes that De Nevo will be able to maintain its 80 mmscf/d for between five to seven years.

With respect to BHP Billiton, the report said the company is expected to produce 460mmscf/d from its Blocks 2 (c). However, BHP will only be selling 320mmscf/d to the National Gas Company because it is keeping 160mmscf/d to re-inject into its oil wells to lift more crude from the Angostura field.

The report notes that in 2019 BHP will move to develop its Ruby-Delaware project.

“This project involves the development of 3(a) with the drilling of several wells—a single deviated well in Delaware and four horizontal oil producers and one gas injector in Ruby. Block 3(a) will use the existing Block 2 (C ) processing facilities,” the Ministry of Energy's report revealed.

Royal Dutch Shell is expected to bring on additional gas this year from its Starfish field. The company announced in May that it had produced first gas from Starfish.

The ministry's report put first gas at a modest 22mmsf/d but noted that two more wells were expected that would increase and hold production at 138 mmscf/d. It would be remembered that Starfish was originally drilled by the then BG Trinidad, which is now Shell, and was a spectacular failure that eventually led to a major shake up at the local company.

The Ministry's report notes that Starfish will be produced using existing subsea infrastructure between the Dolphin platform and Starfish Field. Shell is also expected to add 100MMscf/d from the Dolphin field with the drilling of four wells. The additional gas should come on by the fourth quarter this year.

Shell is also planning two development wells for block 5(c) and one exploration well in 5 (d).

The country's largest gas producer, bpTT, will in the fourth quarter bring on its Angelin field. Angelin, which was originally discovered in 1995, is a dry gas field in the Northern Columbus Basin with reserves of 914 Billion cubic feet. When it comes on stream it has the potential to add up to 600mmcsf/d of gas and will certainly shore up BP's gas production to over 2 bcf/d for the next two years. The gas from Angelin is expected to be used to shore up contractual arrangements with Atlantic LNG.

Gas company bpTT will remain in fairly aggressive mode over the next two years and will drill three development wells in Cannonball and two in Cashima. It will also seek to replicate its success by drilling two exploration wells in 2019 called Ginger and Jasmine.

The ministry's document also shows that bpTT will bring its Cassia compression platform into service in 2020 as it maintains its high production rates from the prolific Columbus basin. It expects its natural gas production to average 202 bcf/d and condensate production of 7,500 barrels of oil per day or more than 20 per cent of total country production of liquids.


Story from Trinidad & Tobago Guardian 07 26 2018

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