Our Assets – Onshore
|Assets||Working Interest %||2P Reserves
The H1 2018 performance metrics summarised above reflected an average oil price realisation of US$60/bbl. Trinity’s strategy is to increase value realisation from the Onshore portfolio with the combination of higher production, higher oil prices during 2018 and the largely fixed cost base enabling a leverage effect on profitability.
- 45% 2P reserves growth from 2016-2017
- Reserves only reflect drilling of defined locations
- Step-change in evaluation efforts in 2017/18
- H1 2018 avg. production of 1,530 bopd
- Direct & proven corollary between activity levels & production growth (low risk)
- Commercial production onshore Trinidad since 1910, has produced 1.6bn bbls (to 2013) with low recovery factor (circa 12.5%-15%) leaving significant remaining potential
- Onshore business offers low risk/predictable exploitation opportunities, with strong cash flow for reinvestment
- Low risk/low cost drilling more akin to mining in a well established hydrocarbon basin
- Drill 8-10 wells per year targeting >10% year-on-year production growth in near term
- Reset base production to over 3,000 bopd (for next 5 years at a minimum)
- Largely fixed operating cost base, so incremental production will result in higher operating earnings
- Free-cash flow generating from 2020, self-funding new Onshore wells thereafter
- Conventional operating environment but reserves rich & low risk
- Low productivity needs to be challenged by application of new technology
- Good quality stacked pay in extensive oil columns
- Low RF’s (c.20%)
- Giant STOIIP (~10 bn bbls) within larger Forest Reserve Field area
- Low energy reservoir system
- Pumping required
- Manpower intensive
- Simple operations
- Opportunity rich
- Potential 3D seismic
- Horizontal wells
- New pumping technologies
Forest Reserve Oil Trend
FZ-2, WD-13 and WD-14
The Fyzabad Oilfield in South Trinidad, was discovered in 1920 by Apex (Trinidad) Oilfield Limited, now the national oil and gas company, Petroleum Company of Trinidad and Tobago Limited (Petrotrin). The principal producing sands are those of the Cruse and Forest Formations which are Upper Miocene to Lower Pliocene in age and deltaic in origin. The API gravity of crude from these sands vary between 22° and 27°. Porosities average 33% in the Forest, and 29% in the Cruse. Structurally, the field is underlain by the Western extremity of the E.N.E. – W.S.W. trending Debe-Wellington Anticline which plunges gently westward and is cut by a series of extensional faults. These faults compartmentalise the fields and are sealed at most reservoir levels. Regional seals and stratigraphic marker horizons across the Forest Reserve Field are the Upper Forest Clay (BUFC) and Lower Forest Clay.
Palo Seco Oil Trend
WD-2 and WD-5/6
The WD-2 and WD-5/6 Blocks are located onshore in South-West Trinidad approximately 20 miles South-West of the city of San Fernando, in the Southern Basin, which consists of productive clastic sediment reservoirs of the Cruse, Forest and Morne L’Enfer Formations. They form part of the Southwestern extension of the Palo Seco and Erin Oilfields. The WD-2 Block lies on the North flank of the Southern Range Anticline (SRA), which is interpreted to be a fault propagated fold structure formed by a series of thrust faults emanating from the North/North-West. Mud volcanoes are associated with these faults where they sometimes break through to surface. This generally occurs in the crest of the anticline, South of the block. The WD-5/6 Block is immediately North of the WD-2 Block, on the South-Eastern flank of the Erin Syncline which trends NE-SW and plunges to the South-West. These blocks also lie South of the Los Bajos fault which trends NW-SE and is a right lateral strike slip fault. The Blocks are structurally compartmentalised by a series of NW/SE and NNE/SSW trending normal faults. The Upper Morne L’Enfer (UMLE) outcrops over the Northern (WD-5/6) areas, whereas the Lower Morne L’Enfer outcrops over the Southern area (WD-2). The Lower Forest and Upper Cruse are the most prolific producers across the blocks. The API gravity of crude from these sands varies between 20° and 31°. Porosities average 30% in the Lower Morne L’Enfer, 30% in the Forest, and 26% in the Cruse.
Factors Controlling Oil and Gas Accumulation
The trapping mechanism in these fields is a combination of both stratigraphy and structure. Both North and South flanks of the anticlines provided extensive area from which oil and gas migrated updip into lenticular sands on the crest and upper flanks of the anticline. Minor faults which are common in the field act as seals to reservoirs, since oil and gas are found downdip of faults below water levels of the same sand in adjacent blocks. In addition to the above trapping mechanisms, unconformities at the tops of Forest and Cruse Formations may have acted as seals, trapping oil and gas in the sand reservoirs below them. In WD-2 and WD-5/6, mud diapirs further compartmentalised the fields and also support pressured reservoir zones.
Central Range Oil Trend
Trinity’s interest in the Tabaquite field is via a Farmout Agreement. The field is located within the Central Range oil trend.
The Tabaquite and Johnson Road fields are located in the Naparima Thrust Fold Belt, which forms part of the Central Range. This thrust fold belt is bounded to the South by the Nariva Thrust Fault and to the North by the Central Range Thrust Fault. Within the belt, at least five (5) sub-parallel thrust faults have been recognised that were formed in response to mid Miocene compression.
The Tabaquite field was discovered in 1911. The crude that was produced was reported to have been of good quality, with a relatively high API gravity.
The Blanket Sand at the base of the Nariva Formation forms a relatively thick unit (up to 100ft) which is laterally extensive across the Tabaquite lease and along strike into Brighton Marine Field. Internal heterogeneity within the Blanket Sand is common, indicating that it comprises multiple stacked thin beds. The overlying Stringer Sands comprise thinner beds of sandstone intercalated with shale.
Locally sand/shale packages are correlatable but individual sands are unlikely to extend laterally for more than a few hundred meters in dip sections. The API gravity of crude from the Nariva and Stringer Sands varies between 28° and 40°. Porosities average 15% in the Nariva Sands and 12% in the Stringer Sands.