Abstract: Migration of Hydrocarbons in Compacting Basins

L. C. Bonham

In the migration of petroleum, either as phases separate from water or in water solution, an important role is assigned to pore-fluid movements which result from the compaction process. The usual view is that progressive burial of the sediments results in their compaction with consequent expulsion of pore fluids. These fluids are pictured as moving upward toward the depositional surface, even though the pathways in detail may include some lateral and downward movement. This commonly accepted view is often incorrect, as can be demonstrated by a simple conceptual model.

In the early stages of basin subsidence and sedimentation, the flux of water with reference to the depositional surface is downward, even though the flux of fluids expelled by compaction is upward across stratigraphic units. In later stages, a deep, subsiding basin contains a more or less constant volume of water. As subsidence, sedimentation, burial, and compaction continue, the sediments can be visualized as slowly moving downward through a fixed volume of water. Relative to a stratigraphic marker, the fluids move upward, but for the most part they do not move to shallower positions relative to the surface of deposition.

When source sediments move downward into the thermal window for hydrocarbon generation, some of the hydrocarbons formed go into water solution. Subsequent migration and release of hydrocarbons from solution depend upon the fluid flux and the positions of the isotherms. Exsolution occurs whenever the temperature of the solution falls below the saturation temperature. To meet this requirement, geologists have proposed that large volumes of deep, hot water are physically transported to shallower, cooler zones. The same exsolution occurs, however, if the waters retain their position relative to the depositional surface while the isotherms are depressed.

These concepts were applied in a petroleum migration study of a representative Gulf Coast producing area. The study involved geologic restoration, uncompaction, and geothermal restoration by means of computer modeling. Results indicate a formation-temperature drop of about 50°F (10°C) since early Pliocene time; a few thousand feet of section below the 200 or 250°F (93 or 121°C) isotherms could have exsolved hydrocarbons equivalent to the total known oil and gas in the area. Some movement upward toward the depositional surface probably occurred when fluids from high-pressure shales leaked through thin sands or along faults. Quantitative modeling shows that the contribution to petroleum migration by this mechanism is small in areas such as the one studied where the section retains abnormally high pressure and above-normal porosities.

AAPG Search and Discovery Article #90961©1978 AAPG Annual Convention and Exhibition, Oklahoma City, Oklahoma