Clarifying the oil type, quantity, and volume, and estimating potential flow rates are the basic components for unlocking heavy oil reservoirs. Because reservoirs are often stacked within a field and different fluid types or varying compositions may be present a variety of production methods, including thermal enhanced oil recovery (EOR), may be required to produce each basin.
During reservoir evaluation studies developers must keep the long-term strategy in mind, selecting the path that leads to the fastest release of cash flow so that, as needed, facilities may be built to enable sequential production from other reservoirs. A pilot project is an essential part of this process.
Reservoir studies delineate the basin’s lateral extent and thickness—from all scales and angles. Seismic services often help define the reservoir’s reach, and when combined with LWD and MWD data and wireline logs, they provide the input to build reliable reservoir models.
To calculate basic economic viability, you need to estimate the volume of hydrocarbons in the reservoir. By combining various measurement types and using specially calibrated tools we can define the difference between oil and water contacts in heavier reservoirs.
One of the biggest challenges in heavy oil fluid characterization is to acquire representative samples of viscous fluids downhole.
Heavy oil reservoirs are often associated with soft, unconsolidated near-surface basins. Wellbore stability can be an issue, and poorly-sorted heterogenous sands can hinder steam chamber growth. In cold heavy oil production with sand (CHOPS), accurate sedimentary classification is also needed to build models.
Schlumberger screens techniques to recommend the best solution for a field, propose and design a pilot project for proof of concept and provide injection, production and surveillance facilities and operation know-how for our customers.
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