Injector-producer well patterns and flooding.Single-well cyclic stimulation (huff-and-puff).Corrosion management in oil production and processing operations.Oil production and processing facilities.Why shale gas wells could be alternative locations for giga-ton-level CO2 sequestration.What are the technical reasons for the increase in CO2 injection operations in the US.Quick review of Enhanced Oil Recovery (EOR) Techniques: what is available out there?.In this new environment the flooding operation occurs only through the fracture network and the recovery of oil from the tight matrix may need large soaking times. However, the existing knowledge on CO2-EOR requires conscious transformation from flooding in well patterns of injectors and producers into the unconventional well settings: horizontal wells with long laterals drilled into ultra-tight formation and hydraulically-fractured densely. Firstly, the unconventional reservoirs are the most suitable for mobilization of oil: high pressure reservoirs with high API gravity oil. CO2-injection has the potential to play an important role in reaching these targets. The major reasons for the success in CO2-EOR are (1) high efficiency of CO2 in mobilizing crude oils with a wide range of API under the reservoir conditions, (ii) difficulty in injecting water (and water with chemicals) into deep oil reservoirs and (iii) low efficiency of thermal recovery methods with deep light oil reservoirs.Ĭurrently the unconventional oil and gas industry is under economic and social pressure to (i) maintain low-cost production from shale gas/oil wells, (ii) reduce the environmental footprint during the field operations, and (iii) reach to net-zero targets. Currently, CO2 flooding makes up the largest proportion of the total EOR projects in the US. Since then, a significant body of knowledge has developed, which led to numerous field-applications globally. National Petroleum Council recognized the potential for CO2-enhanced oil recovery and initiated the first laboratory investigations on CO2 flooding in 1950s. Standardizing texture ensures that the principles of process sedimentology are consistently applied to compositionally variable rock sequences, such as mixed carbonate–siliciclastic ramp settings, and the extreme ends of depositional systems.The U.S. Folk's (1980) ternary diagram for fine-grained clastic sediments (sand, silt, and clay size fractions) is also revised to preserve consistency with the revised diagram for gravel, sand, and mud. Hydrofacies codes are nondirectional permeability indicators that predict aquifer or reservoir potential. These modifications provide bases for standardizing vertical displays of texture in graphic logs, lithofacies codes, and their derivatives-hydrofacies. The new classification ensures that descriptors are applied consistently to all end members in the ternary diagram (gravel, sand, and mud) according to several rules, and that none of the end members are ignored. Revised textural fields, or classes, are based on a strict adherence to volumetric estimates of percentages of gravel, sand, and mud size grain populations, which by definition must sum to 100%. The revised ternary diagrams include additional textural fields that better define poorly sorted and coarse-grained deposits, so that all end members (gravel, sand, and mud size fractions) are included in textural codes. Modifications to Folk's (1980) texturally based classification that include applying new assumptions and defining a broader array of textural fields are proposed to accommodate this. The classification is contingent on defining the term “clastic” so that it is independent from composition or origin and includes any particles or grains that are subject to erosion, transportation, and deposition. Proposed here is a universally applicable, texturally based classification of clastic sediment that is independent from composition, cementation, and geologic environment, is closely allied to process sedimentology, and applies to all compartments in the source-to-sink system.