Carbonate Reservoir—Near Wellbore Scale

As carbonate rock has been compressed over geological time, its character has changed from its original state due to diagenesis. This process will have caused the pores to change in size and geometry and may also have created stylolite flow barriers over large areas. Evaluating the complex heterogeneous rock can therefore be very problematic, particularly as rock properties may vary greatly across the field.

Porosity, permeability and saturation are therefore some of the most important factors for reservoir modeling and production planning.

Rock Properties

Fluid Saturation

Measurement Integration

Fracture Detection

Productive Zones

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Diagenesis Determines Reservoir Quality

Diagenesis and Reservoir Quality
Diagenesis comprises all processes that convert raw sediment to sedimentary rock, and ultimately determines the viability of the reservoir. Read industry article

Increasing the Length Scale for Permeability Answers

MDT multiprobe and packer-probe configurations offer options for vertical interference testing.Comparison of CMR-derived permeability, core and MDT pretest values. The interference test locations are shown on the formation image.Mini-DST analysis of Test 1. The probe did not show any response during the test, suggesting a possible barrier. Analysis indicates spherical and radial flow.
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