Potential Basin-Centered Gas Accumulation in Cretaceous Trinidad Sandstone, Raton Basin, Colorado

Rose, Peter R.; Everett, John R.; Merin, Ira S.

doi:10.1306/st24459c6

Cited by 8 publications

(3 citation statements)

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“…A lot of research, exploration and development practices so far show that there are mainly three types of gas flow/migration driving forces in tight sandstone gas reservoirs, which result in the three corresponding gas-water accumulation and distribution patterns. (1) The continuous distribution model in deep basin/basin center: The concept of deep basin gas was first proposed by Masters (1979) [9], while basin-center gas was proposed by Rose et al (1984) and Law (2002) [10,11]. The concept of "continuous accumulation" was first advanced by the US Geological Survey in the mid-1990s [12,13].…”

Section: Introductionmentioning

confidence: 99%

Driving Forces of Natural Gas Flow and Gas–Water Distribution Patterns in Tight Gas Reservoirs: A Case Study of NX Gas Field in the Offshore Xihu Depression, East China

He,

Li,

Duan

et al. 2023

Energies

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The driving forces behind gas flow and migration, as well as the associated gas–water distribution patterns in tight gas reservoirs, are not only closely related to the formation mechanisms of “sweet spots”, but also serve as crucial geological foundations for the development of efficient modes and optimal well placement. In this work, three methods, namely, critical gas column height driven by buoyancy, critical pore throat radius driven by buoyancy, and gas–water distribution attitude, were used to quantitatively evaluate the critical conditions for buoyancy and overpressure to get gas flowing in the tight sandstone gas field. In light of the geological background, the driving forces of gas flow/migration and gas–water distribution patterns were comprehensively analyzed. On this basis of the origins of overpressure driving gas flow/migration were identified by using multiple empirical methods, the evolution of overpressure and characteristics of gas–water distribution driven by overpressure were studied by using PetroMod_2014 simulation software. The results show that the four main gas-bearing layers in the NX tight sandstone gas reservoir differ widely in gas flow/migration dynamics and gas–water distribution patterns. Gas accumulation in the H3b layer is influenced by both buoyancy and overpressure. Subsequently, buoyancy leads to the differentiation of gas from water based on density and the formation of edge water. Furthermore, the distribution area of the gas reservoir is determined by the presence of an anticline trap. In contrast, in H3a, H4b and H5a gas layers, buoyancy is not sufficient to overcome the capillary force to make the gas migrate during and after accumulation, and the driving force of gas flow is the overpressure formed by fluid volume expansion during hydrocarbon generation of Pinghu Formation source rocks. Because buoyancy is not the driving force of natural gas flow, H3a, H4b and H5a layers have gas and water in the same layer and produced together, and no boundary and bottom water, where the anticlinal trap does not control the distribution of gas and water, and gas source faults control the boundary of the gas reservoir. These understandings not only significantly expand the gas-bearing target of H3a, H4b and H5a gas layers delineated in the buoyancy driving pattern but also provide an important geological basis for the formulation of an efficient development plan by class and grade for the NX tight sandstone gas field.

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Section: Introductionmentioning

confidence: 99%

Driving Forces of Natural Gas Flow and Gas–Water Distribution Patterns in Tight Gas Reservoirs: A Case Study of NX Gas Field in the Offshore Xihu Depression, East China

He,

Li,

Duan

et al. 2023

Energies

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“…Tight gas reservoirs were firstly discovered several decades ago and have been raising attention of geologists, since easily exploitable conventional reserves are to be exhausted (Dai et al, 2012;Jiang et al, 2006;Law, 2002;Law and Spencer, 1993;Masters, 1979;Rose et al, 1984;Schmoker, 2002). The tight sandstone gas refers to the gas trapped in reservoirs with porosity less than 10% and in-situ permeability less than 1 mD (Zou et al, 2012(Zou et al, , 2013.…”

Section: Introductionmentioning

confidence: 99%

Conventionally trapped natural gas accumulations in the Jurassic tight sandstone reservoirs: A case study from the Center of the Western Sichuan Basin, SW China

Guo

Song

Fang

et al. 2017

Energy Exploration & Exploitation

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Tight gas accumulations, commonly characterized by low permeability, low porosity, and complicated pore structure, are widely distributed in the Sichuan Basin. Recent exploration in the Chengdu Sag, Western Sichuan Basin has proven that Jurassic tight-sandstone reservoirs attach significant gas potential. However, long distance migration between source and reservoir intervals entangles understanding of the tight-gas accumulation mechanism. It is unclear whether producible gas in Jurassic intervals is either from ''simple sweet-spots in a continuous accumulation'' or ''conventionally trapped accumulations in low-permeability reservoir rocks''. To identify the regionally active gas system and characterize the charging pattern, a geochemical study was performed by interpreting the gas molecular and carbon isotope compositions in Jurassic and conducting gas-source correlations as well as gas migration distance calculation with the relationship among d 13 C 1 vs. R o vs. H (burial depth). Research results indicate that the Jurassic tight gases in Majing-Shifang areas are coal-derived dry gases generated by the primary cracking of kerogen. Gas/source correlation and gas migration distance calculation reveal that gases are mainly sourced from the Upper Triassic humic source rocks (T 3 x 5 , the fifth member of the Xujiahe Formation). Gas accumulations in the Jurassic Penglaizhen Formation were formed with an original vertical migration of about 2-3 km and then a long-distance lateral migration within tight sand layers, which is verified by the decreasing d 13 C 1 and the general increasing iC 4 /nC 4 in the Penglaizhen Formation. The Jurassic tight-sandstone reservoirs in Majing-Shifang areas occur in low-porosity and low-permeability reservoir rocks in conventional lithological traps, which are not continuous-type gas accumulations or basin-centered gas systems. The faults in Majing area serve as dominant vertical conducting pathway and the relatively permeable

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“…Tight gas was the unconventional nature gas exist in the tight sandstone that has the extremely low permeability, the porosity of this tight sandstone general less than 12%, the permeability general less than 10 -4 D, the saturation of gas less than 60%, the saturation of water more than 40%, the natural production of signal well always lower than floor level of industrial gas flow, but its can get the industrial gas flow through some method [5,6] . Compare with the conventional nature gas, the tight gas reservoirs has the characteristic of low permeability, low porosity, reservoir pressure abnormal, has the complicated relationship between gas and water, the reservoir forming relationship intimate between deep layer and superficial layer, the mainly type of gas was free, but it has the adsorption gas basic on the different geological conditions, general about 10%~20% [7] .…”

Section: Introductionmentioning

confidence: 99%

Study and Apply of Seepage Law on Multi-Stage Fractured Horizontal Wells in Tight Gas Reservoirs

Wang

Xia

Wei

et al. 2014

AMR

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Because the extremely low permeability for tight gas reservoirs, lead to the way to seepage and the shape of production curves different with the convention reservoirs; this will increase the difficulty to develop the tight gas reservoirs; on the other hand, the convention exploit cannot recover the tight gas with commercial value, with this problem, the main solution is the technology of multi-stage fractured horizontal wells, the fractured can provide the channel for gas to transport, the horizontal wells can increase the seepage area of tight gas, it’s the guarantee to get the commercial value. But, at present, the study on the tight was dependent on the method of convention gas reservoirs, the production curve get from this method also the same with the convention gas reservoirs, in order to close with the really exploitation of tight gas reservoirs and provide the more accurate scientific evidence, we must study based on the feature of tight gas reservoir, in this situation, we can get the suitable production curves for tight gas reservoirs. This paper based on the feature of tight gas reservoir, combine with the model of multi-stage fractured horizontal wells, and get the production equation of tight gas, combine with the yield of discard time, we can get the type curve, and then get the C level reserves of region.

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Potential Basin-Centered Gas Accumulation in Cretaceous Trinidad Sandstone, Raton Basin, Colorado

Cited by 8 publications

References 0 publications

Driving Forces of Natural Gas Flow and Gas–Water Distribution Patterns in Tight Gas Reservoirs: A Case Study of NX Gas Field in the Offshore Xihu Depression, East China

Driving Forces of Natural Gas Flow and Gas–Water Distribution Patterns in Tight Gas Reservoirs: A Case Study of NX Gas Field in the Offshore Xihu Depression, East China

Conventionally trapped natural gas accumulations in the Jurassic tight sandstone reservoirs: A case study from the Center of the Western Sichuan Basin, SW China

Study and Apply of Seepage Law on Multi-Stage Fractured Horizontal Wells in Tight Gas Reservoirs

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