Foam processes in naturally fractured carbonate oil-wet reservoirs: Technical and economic analysis and optimization

Bouquet, Sarah; Douarche, F.; Roggero, F.; Bourbiaux, B.

doi:10.1016/j.petrol.2020.107111

Cited by 10 publications

(6 citation statements)

References 25 publications

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“…Bouquet et al proposed an economic evaluation of the EOR process using foam and CO 2 , where operation expenditures (OPEX) are mainly calculated, and capital expenditures (CAPEX) are not considered. 50 The economics was quantified with the cash flow (CF), which is the difference between income and cost per month: CF( n ) = π o ( V o n − V o n −1 ) − [π w ( V w n − V w n −1 ) + π g ( V g n − V g n −1 ) + π f ( M f n − M f n −1 )] where V o,w,g n is the cumulative volume of produced oil, injected water and gas at month n since the beginning of cycling, and M f n is the cumulative mass of the foaming agents. π o is the oil price, $ per bbl.…”

Section: Resultsmentioning

confidence: 99%

Section: Pilot Tests Of N 2 -Foam-assisted Co 2 Huff-n-puffmentioning

confidence: 99%

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N₂-foam-assisted CO₂ huff-n-puff process for enhanced oil recovery in a heterogeneous edge-water reservoir: experiments and pilot tests

et al. 2021

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Section: Resultsmentioning

confidence: 99%

Section: Pilot Tests Of N 2 -Foam-assisted Co 2 Huff-n-puffmentioning

confidence: 99%

N₂-foam-assisted CO₂ huff-n-puff process for enhanced oil recovery in a heterogeneous edge-water reservoir: experiments and pilot tests

et al. 2021

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“…Examples of such functions can be found in [15][16][17]20] and cited references therein. Estimation of M ref from measurements is detailed in Appendix A.…”

Section: Darcy-scale Model Types and Driving Equationsmentioning

confidence: 99%

“…To finish with, we do not consider chemicals adsorption nor the impact of NAPL on foam in this work since they both primarily impact economics and chemicals slug size, which is not the topic addressed here. Of course, they are of critical interest for technical and economical evaluation (the reader is referred to [20] for such an evaluation for naturally fractured oil-wet reservoirs, e.g.). It is also assumed that the reservoir can withstand the imposed injection flow rate without suffering from any injectivity issues due to pressure build-up.…”

Section: Static Picture Dynamic Picture Observationmentioning

confidence: 99%

Foam placement for soil remediation: scaling foam flow models in heterogeneous porous media for a better improvement of sweep efficiency

Douarche,

Braconnier,

Bourbiaux

2023

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If injected with a large gas fraction, foam reduces mobility more in high-permeability layers and diverts flow to low-permeability layers. Here is a qualitative statement that has been claimed many times in many works related to environmental remediation and oil recovery. It is so true and relevant for foam flow in porous media and yet so little quantified and even less exploited in Darcy-scale numerical simulation. After briefly reviewing opportunities and challenges related to the use of foams in porous media and its Darcy-scale implicit-texture and population-balance modelling, we make a detour out of the strict framework of mathematical models by revisiting with a fresh eye the physics of foams on the large scale of heterogeneous natural porous media in terms of scaling laws. Specifically, it has been recently shown experimentally and theoretically that foam mobility reduction scales approximately as the square root of rock permeability within the framework of Darcy-type implicit-texture foam flow models [Douarche et al. (2020) Scaling foam flow models in heterogeneous reservoirs for a better improvement of sweep efficiency (Paper ThB04), in:17th European Conference of the Mathematics of Oil Recovery (ECMOR), Edinburgh, Scotland, 14–17 September; Gassara et al. (2020) Trans. Porous Media 131, 1, 193–221]. This also appears to hold for population-balance models under the local steady state assumption. This quantitative scaling law for the effect of permeability on foam properties was inferred from an analogy between foam flow in porous media and foam flow in capillary tubes and was found consistent with the modelling of available experimental data. We demonstrate by varying the permeability contrast and anisotropy of a stack of porous layers how foam regulates the flow and leads to flow diversion from high- to low-permeability layers. The threshold in permeability heterogeneity for which such a foam-driven diversion becomes effective is quantified through a sensitivity study accounting for foam injection type, permeability heterogeneity and anisotropy, heterogeneity structure, and scaling procedure. The simulations carried out clearly indicate that ignoring mobility reduction dependence on permeability in the foam process assessment of heterogeneous formations leads to an underestimation of mobility reduction benefits to improve flow conformance. The question of cores selection, as this rock-typing strategy in relation to the porous medium characterization may guide a smart and optimal design of pre-feasibility laboratory campaign for foam evaluation, and the generalization of the findings to multi-facies geological formations are also discussed. As such, the use of physical foam mobility reduction scaling law is highly recommended for foam process evaluation.

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“…The most important source of knowledge on productivity of oil and gas reservoirs and the whole field as a whole is information on such petrophysical characteristics as carbonate, porosity, permeability, density, grain size distribution, sealing and elastic properties (longitudinal wave velocity) of the rocks. The research also estimated the average values of physical characteristics, the dependence of reservoir properties on the occurrence depth and the relationship of physical parameters [1][2][3][4].…”

Section: Introductionmentioning

confidence: 99%

Petrophysical characteristic of deep oil and gas reservoirs in inland and offshore fields in Azerbaijan

Kerimov¹,

Gasanov²,

Abbasova³

et al. 2020

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Foam processes in naturally fractured carbonate oil-wet reservoirs: Technical and economic analysis and optimization

Cited by 10 publications

References 25 publications

N₂-foam-assisted CO₂ huff-n-puff process for enhanced oil recovery in a heterogeneous edge-water reservoir: experiments and pilot tests

N₂-foam-assisted CO₂ huff-n-puff process for enhanced oil recovery in a heterogeneous edge-water reservoir: experiments and pilot tests

Foam placement for soil remediation: scaling foam flow models in heterogeneous porous media for a better improvement of sweep efficiency

Petrophysical characteristic of deep oil and gas reservoirs in inland and offshore fields in Azerbaijan

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Foam processes in naturally fractured carbonate oil-wet reservoirs: Technical and economic analysis and optimization

Cited by 10 publications

References 25 publications

N2-foam-assisted CO2 huff-n-puff process for enhanced oil recovery in a heterogeneous edge-water reservoir: experiments and pilot tests

N2-foam-assisted CO2 huff-n-puff process for enhanced oil recovery in a heterogeneous edge-water reservoir: experiments and pilot tests

Foam placement for soil remediation: scaling foam flow models in heterogeneous porous media for a better improvement of sweep efficiency

Petrophysical characteristic of deep oil and gas reservoirs in inland and offshore fields in Azerbaijan

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Product

Resources

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N₂-foam-assisted CO₂ huff-n-puff process for enhanced oil recovery in a heterogeneous edge-water reservoir: experiments and pilot tests

N₂-foam-assisted CO₂ huff-n-puff process for enhanced oil recovery in a heterogeneous edge-water reservoir: experiments and pilot tests