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    • 专利摘要:
    Process for operating a hydrocarbon reservoir by gas injection in the form of a foam, comprising a step of determining a model for displacing the foam, this model being a function of an optimal gas mobility reduction factor and at least one interpolation function dependent on the water saturation. The optimum gas mobility reduction factor is determined and the constants of the water saturation interpolation function are calibrated from a plurality of apparent viscosity measurements for different values of the quality of the foam, and using a lamella model to connect the lamella density as a function of water saturation. Application in particular to the exploration and the oil exploitation.
    公开号:FR3062672A1
    申请号:FR1750940
    申请日:2017-02-03
    公开日:2018-08-10
    发明作者:Omar GASSARA；Frederic DOUARCHE；Benjamin BRACONNIER；Bernard Bourbiaux
    申请人:IFP Energies Nouvelles IFPEN；
    IPC主号:
    专利说明:

    ® FRENCH REPUBLIC
    NATIONAL INSTITUTE OF INDUSTRIAL PROPERTY © Publication number: 3,062,672 (to be used only for reproduction orders) (© National registration number: 17 50940
    COURBEVOIE © Int Cl 8 : E 21 B 43/16 (2017.01), E 21 B 43/20
    A1 PATENT APPLICATION
    (© Date of filing: 03.02.17. © Applicant (s): IFP ENERGIES NOUVELLES Etablis- (© Priority: public education - FR. @ Inventor (s): GASSARA OMAR, DOUARCHE FREDERIC, BRACONNIER BENJAMIN and BOUR- (43) Date of public availability of the BAUX BERNARD. request: 10.08.18 Bulletin 18/32. (© List of documents cited in the report of preliminary research: Refer to end of present booklet (© References to other national documents ® Holder (s): IFP ENERGIES NOUVELLES Etablisse- related: public. ©) Extension request (s): © Agent (s): IFP ENERGIES NOUVELLES.
    FR 3 062 672 - A1 (04) PROCESS FOR THE EXPLOITATION OF A OIL DEPOSIT BY INJECTION OF A GAS IN THE FORM OF FOAM.
    ©) Process for exploiting a hydrocarbon deposit by injecting gas in the form of foam, comprising a step of determining a model for displacement of the foam, this model being a function of a factor of reduction of mobility of the optimal gas and at least one interpolation function dependent on water saturation.
    The optimal mobility reduction factor of the gas is determined and the constants of the interpolation function relating to water saturation are calibrated from a plurality of apparent viscosity measurements for different values of the quality of the foam, and by means of a lamella model allowing the density of lamellae to be linked as a function of water saturation.
    Application in particular to petroleum exploration and exploitation.
    The present invention relates to the field of the exploitation of a fluid contained in an underground formation, more particularly the assisted recovery of a fluid, such as a hydrocarbon fluid, by injection of foam.
    The exploitation of an oil reservoir by primary recovery consists in extracting, via a so-called production well, the oil present from the reservoir by the overpressure effect prevailing naturally within the reservoir. This primary recovery only gives access to a small quantity of the oil contained in the reservoir, of the order of 10 to 15% at most.
    To allow further extraction of the oil, secondary production methods are used, when the reservoir pressure becomes insufficient to move the oil still in place. In particular, a fluid is injected (re-injection of the water produced diluted or not, injection of sea or river water, or injection of gas, for example) into the hydrocarbon tank, with a view to exerting within the tank an overpressure capable of entraining the oil towards the production well or wells. A common technique in this context is the injection of water (also known by the English term "waterflooding"), in which large volumes of water are injected under pressure into the reservoir via injector wells. The injected water entrains part of the oil it encounters and pushes it towards one or more producing wells. Secondary production methods such as water injection, however, only extract a relatively small part of the hydrocarbons in place (typically around 30%). This partial sweep is due in particular to the trapping of the oil by capillary forces, to the differences in viscosity and density existing between the injected fluid and the hydrocarbons in place, as well as to heterogeneities on micro- or macroscopic scales (scale pores and also tank scale).
    To try to recover the rest of the oil, which remains in the underground formations at the end of the implementation of the primary and secondary methods of production, there are different techniques called assisted recovery (known by the acronym "EOR >> , corresponding to "Enhanced Oil Recovery"). Among these techniques, mention may be made of techniques akin to the aforementioned injection of water, but employing water comprising additives such as, for example, water-soluble surfactants (this is known as " surfactant flooding ”). The use of such surfactants in particular induces a reduction in the water / oil interfacial tension, which is capable of ensuring a more effective entrainment of the trapped oil at the level of the pore constrictions.
    Also known is assisted recovery by injection of gases, miscible or not (natural gas, nitrogen or CO 2 ). This technique makes it possible to maintain the pressure in the petroleum tank during its operation, but can also make it possible, in the case of miscible gases, to mobilize the hydrocarbons in place and thus to improve the flow thereof. A commonly used gas is carbon dioxide when available at low cost.
    Alternative techniques are also known based on an injection of foam into the petroleum tank. This foam results from the intimate mixture of gases and a solution of a surfactant additive, the latter being designated "foaming agent" in the following. Due to its high apparent viscosity, foam is considered an alternative to gas as an injection fluid in hydrocarbon tanks. The mobility of the foam is thus reduced relative to the gas which, on the other hand, tends to segregate and rapidly pierce in producing wells, in particular in heterogeneous and / or thick reservoirs. The assisted recovery by injection of foam is particularly attractive because it requires the injection of smaller volumes than for other assisted recovery processes based on non-foaming fluids.
    State of the art
    The following documents will be cited in the following description:
    Alvarez, J. M., Rivas, H. J. and Rossen, W. R .. 2001. Unified Model for Steady-State Foam Behavior at High and Low Foam Qualities. SPE Journal, 6 (3): 325-333.
    Boeije, C. S. and Rossen, W. R..2015. Fitting Foam-Simulation-Model Parameters to Data: I. Coinjection of Gas and Liquid. SPE Reservoir Evaluation & Engineering, 18 (2), 264272.
    Bretherton F. P. 1961. The motion of long bubbles in tubes. Journal of Fluid Mechanics, 10 (2): 166.
    Farajzadeh, R., Lotfollahi, M., Eftekhari, A.A., Rossen, W.R. and Hirasaki, G.J., 2015. Effect of Permeability on Implicit-Texture Foam Model Parameters and the Limiting Capillary Pressure. Energy & Fuels 29, 3011-3018 (ACS Publications).
    Hirasaki, G. J. and Lawson J. B. 1985. Mechanisms of foam flow in porous media: apparent viscosity in smooth capillaries. SPE Journal, 25 (2): 176-190.
    Kapetas, L., Vincent-Bonnieu, S., Farajzadeh, R., Eftekhari, A.A., Mohd-Shafian, S.R.,
    Kamarul Bahrim, R.Z. and Rossen, W.R., 2015. Effect of Permeability on Foam-Model Parameters - An Integrated Approach from Coreflood Experiments through to Foam Diversion Calculations. 18th European Symposium on IOR, Dresden, 14-16 April.
    Lotfollahi, M., Farajzadeh, R., Delshad, M., Varavei, A. and Rossen, W. R. 2016. Comparison of Implicit-Texture and Population-Balance Foam Models. Journal of Natural Gas Science and Engineering, 31, 184-197.
    Ma, K., Lopez-Salinas, J.L., Puerto, M.C., Miller, C.A., Biswal, S.L., Hirasaki, G.J., 2013. Estimation of Parameters for the Simulation of Foam Flow through Porous Media. Part 1: The Dry-Out Effect. Energy & Fuels 27, 2363-2375 (ACS Publications).
    Zeng, Y., Muthuswamy, A., Ma, K., Le, W. Farajzadeh, R., Puerto, M., VincentBonnieu, S., Eftekhari, AA, Wang, Y., Da, C., Joyce, JC, Biswal, SL and Hirasaki, GJ 2016. Insights on Foam Transport From a Texture-lmplicit Local-Equilibrium Model with an Improved Parameter Estimation Algorithm. Industrial & Engineering Chemistry Research, 55 (28): 7819-7829, 2016.
    The petroleum exploitation of a deposit consists in determining the zones of the deposit presenting the best petroleum potential, in defining exploitation diagrams for these zones (in order to define the type of recovery, the number and the positions of the exploitation wells allowing an optimal recovery of hydrocarbons), to drill exploitation wells and, in general, to set up the production infrastructures necessary for the development of the deposit.
    In the case of recovery assisted by injection of foam, the definition of an operating scheme for an oil tank may require simulating numerically, as realistically as possible, the flows in the presence of foam in the tank considered. Such a simulation is carried out using a flow simulator comprising a foam displacement model.
    Such a model may require assessing the performance of the foam in terms of reduced mobility. In general, this estimate involves carrying out laboratory experiments consisting in measuring the pressure losses during displacement of foam on the one hand, of water and non-foaming gas on the other hand in a sample of the oil tank. Then, this model of displacement of the foam, representative of the flows on the laboratory scale, is calibrated on the tank scale before carrying out the numerical simulations of the flows, in order to predict the benefit obtained by the injection of the foam in terms of improving the efficiency of movement of the fluids in place.
    The foam displacement models used by the industry are relatively simple models which, under the conditions of existence of the foam, simulate only the effects of the foam in terms of reduced mobility and not the generation-destruction processes. foam. In general, the foam displacement models depend non-linearly on many parameters (calibration constants). Determining the parameters of these models therefore involves solving a nonlinear inverse problem. However, the complexity of moving a foam in a confined medium that constitutes any natural porous medium makes calibration and modeling difficult because the large number of parameters influencing the foam can lead to indeterminacies (multiple solutions).
    We know the approaches proposed in the documents (Ma et al., 2013; Boeije and Rossen 2015; Zeng et al. 2016) which consist in simultaneously determining certain parameters of the foam displacement model by a graphical approach, possibly supplemented by a digital adjustment.
    We also know the techniques proposed in the documents (Farajzadeh et al. 2015; Lotfollahi et al. 2016) which consist in determining the unknown parameters (calibration constants) of the foam displacement model by an iterative numerical least squares approach. However, the problem posed being non-linear vis-à-vis these unknowns, there is no uniqueness of the solution, or in other words, the parameters thus determined are one solution among others possible (cf. for example Kapetas et al., 2015).
    Patent application FR 16/57393 (filing number) is also known, which describes the determination of the parameters of the foam displacement model sequentially, from different sets of experimental data acquired on various rock-fluid-foam systems. characterized in particular by various qualities of foam, various concentrations of foaming agent, various oil saturations. The sequential character of the adjustment of the parameters of the displacement model of the foam makes it possible to minimize the numerical adjustments, contrary to processes carrying out a global adjustment, while trying to extract the maximum of information on the dynamic behavior of the foam from experimental data. The process then provides a model of displacement of the foam, called empirical, faithfully reproducing the experimental data.
    The present invention describes a method for calibrating the foam displacement model intended for reservoir simulation taking into account physical laws relating to foams and their flow properties. More specifically, the present invention describes the use of a lamella model as an intermediate to calibrate the foam displacement model from the experimental data. In this way, the calibration being based on physical laws, the displacement model of the calibrated foam is more realistic and allows, using a tank simulator, more reliable production forecasts. The process according to the invention thus contributes to a better evaluation of the foam-based enhanced recovery processes for recovering the oil from the tank in question.
    The method according to the invention
    Thus, the present invention relates to a method for the exploitation of an underground formation comprising hydrocarbons, by means of an injection of an aqueous solution comprising a gas in the form of foam and of a flow simulator resting on a displacement model of said gas in the form of foam, said displacement model being a function of a mobility reduction factor of said optimal gas and at least one interpolation function of said optimal mobility reduction factor, said interpolation function being a function at least of the water saturation and of at least one constant.
    According to the invention, from at least a sample of said formation, and from conventional relative permeability measurements to the aqueous phase and from conventional relative permeability measurements to gas:
    A- at least said mobility reduction factor of said optimal gas and said constant of said interpolation function are determined according to at least the following steps:
    i. an injection is carried out at constant total speed into said sample of said gas in the form of foam for a plurality of values of the quality of the foam, and an apparent viscosity is measured for each of said values of the quality of the foam;
    ii. from said conventional relative permeability measurements and said apparent viscosity measurements for the plurality of foam quality values, a water saturation is determined for each of said foam quality values;
    iii. from a lamella model as a function of said water saturation and said conventional relative permeability measurements of gas and said aqueous phase, a value of the texture of the foam is determined for each of said values the quality of the foam;
    iv. from said texture values, at least said mobility reduction factor of said optimal gas and said constant of said interpolation function of said optimal mobility reduction factor are determined;
    B- from said displacement model and from said flow simulator, an optimal exploitation scheme for said deposit is determined and said hydrocarbons are exploited.
    According to an implementation of the invention, said apparent viscosity relative to a value of the quality of the foam can be determined from a pressure drop measurement in said sample for said value of the quality of the foam.
    According to one embodiment of the invention, said lamellar model may consist of a function relating the texture of the foam to the water saturation according to a formula of the type:
    Cf n f
    HA g n-rgmax < f v / 3
    J e Ut f, —a „¢ 3, where“ is the quality of the foam, p w the viscosity of the aqueous phase, μ 9 the speed of the gaseous phase in continuous form, Ut is the total speed of the gas and the solution, C f a constant for the rock-fluids system considered, es t | a maximum value of the permeability relative to water, ^ rgmax is the maximum value of the permeability relative to gas, 5 ^ is the gas saturation, φ is the porosity, a, is the exponent of the power function representative of said water permeability measurements, and a, is the exponent of the power function representative of said gas permeability measurements, and 5 is the normalized water saturation.
    w
    According to an implementation of the invention, said model of displacement of the foam may also be a function of at least one interpolation function F k depending on a parameter Vk different from the water saturation, and in which previously in step B) and for each of said interpolation functions F k , steps i) to iii) are repeated for different values of the parameter Vk of said interpolation function F k , and the constants relating to said function are determined interpolation F k from said optimal mobility reduction factor and a mobility reduction factor relating to said interpolation function
    F k .
    Preferably, said parameter Vk can be chosen from a concentration of foaming agent, oil saturation, and a gas flow rate.
    According to an implementation of the invention, said mobility reduction factor Afmod relating to the function F k can be written according to a formula of the type:
    F k (VÙ
    MLd-1
    MX'd-1 or opt mod is said to be the optimal mobility reduction factor.
    Other characteristics and advantages of the method according to the invention will appear on reading the following description of nonlimiting examples of embodiments, with reference to the appended figures and described below.
    Brief presentation of the figures
    Figure 1 shows the evolution of the water saturation and the standardized texture as a function of the quality of the foam.
    Figure 2 shows the evolution of the normalized texture as a function of water saturation.
    Detailed description of the process
    The following definitions are used:
    foam: this is a phase dispersed in another phase by the addition of a foaming agent in one of the two phases. One of the phases can be an aqueous solution and the other phase is a gas, such as natural gas, nitrogen or CO 2 . The flow of foam in a porous medium is macroscopically comparable (on the scale of a sample such as a carrot) to the flow of a single homogeneous phase obeying Darcy's monophasic law, but whose viscosity , called “apparent viscosity” below, is much higher (on the order of 100 to 1000 times more, or even more) than that of the gas which essentially constitutes it
    - lamellar model: also known as the bubble model, it is a dynamic model based on a discontinuous representation of the foam, more precisely as a succession of lamellae (or bubbles) whose volume density (number lamellae or bubbles per unit volume) determines the reduction in foam mobility. Lamella models predict the effects of foam in terms of reduced mobility and also describe the mechanisms of generation and distribution of lamellae in porous media. Thus, the variable of these lamella models is the density of lamellae, and not the saturation as in the reservoir models for conventional industrial use.
    - foam quality: this is the ratio of the gas flow rate w g to the total solution + gas flow rate. In the case where the solution is an aqueous solution, injected at a flow rate u w , the quality of the foam f g can be written in the form:
    dc + uj
    Thus defined, the respective flow rates of the solution and of the gas determine a value f 9 of the quality of the foam.
    In general, one of the objects of the invention relates to a method of operating an underground formation comprising hydrocarbons, by means of an injection of an aqueous solution comprising a gas in the form of foam, and in particular the determination of a scheme for exploiting the hydrocarbons of the underground formation studied. In particular, the method according to the invention aims to determine the parameters of a gas displacement model in the form of foam.
    The method according to the invention requires having:
    - a sample of the underground formation studied, taken by coring in situ for example;
    - a flow simulator based on a gas displacement model in the form of foam (see below);
    - measures of conventional relative permeabilities to gas in non-foaming form and measurements of conventional relative permeabilities to the aqueous phase: these may be measurements carried out expressly for the need of the process according to the invention (the specialist is fully aware of how to conduct such laboratory experiments), but it can also be pre-established curves, or analytical functions calibrated from correlations well known to the specialist.
    The method according to the invention requires having a flow simulator comprising a foam displacement model. According to the invention, the foam displacement model is based on the assumption that the gas present in the form of foam sees its mobility reduced by a given factor under fixed conditions of formation and flow of the foam. The formulation of such a model, used by many flow simulators, consists of a modification of the only gas permeabilities when the gas is present in the form of foam, which, for a given gas saturation S g , s expresses according to a formula of the type:
    k ™ (, S g ) = FM kr g (, Sg) 0) where Krg is the permeability relative to gas in the form of foam, which is expressed as the product of an FM function by the permeability relative to non-foaming gas KRG (.sg) F or the same value of gas saturation s g (denoted s further ° F g) · An underlying assumption foam current models is the permeability relative to water (or liquid extension) is assumed to be unchanged, whether the gas is present in the form of a continuous phase or in the form of foam. In this hypothesis, the mobility reduction functional (2) of the gas, denoted FM thereafter, is expressed according to a formula of the type:
    FM = -ik where:
    - A / mÔ d is the optimal mobility reduction factor, that is to say the ratio of the permeabilities relating to the gas (k rg ) and to the foam under optimal conditions for reducing the mobility of the gas, it is i.e. the conditions under which the terms Fk (y k ) defined below are equal to 1, that is:
    Piss) 1 VJ g-, opt J g, optJ
    FM (3) opt
    - the terms Fk (V (with k equal to or greater than 1) are the values of the functions Fk of interpolation of the mobility reduction factor between the value and l, which each depend on a parameter y k relating to at least one characteristic of the foam, and which involve a certain number of calibration constants to be calibrated as explained below.
    According to the invention, the foam displacement model comprises at least one interpolation function (conventionally denoted F 2 ) depending on a relative parameter (denoted V 2 ) corresponding to the water saturation s w - According to a setting work of the invention, the interpolation function F 2 is written according to a formula of the type:
    Q5 ! arctan [(9 w (5 w -5K)] π (4)
    According to this formulation, the constants of the foam displacement model are the optimal mobility reduction factor y / Xitel that defined according to equation (2), the constant 6F which governs the transition (as a function of water saturation) between the foaming and non-foaming states and the constant s * v which represents the water saturation of transition between stable and unstable foaming states.
    According to one embodiment of the invention, the gas mobility reduction functional, denoted FM, comprises four interpolation functions F ^ CVJet each of these functions comprises two constants to be calibrated from experimental data. According to an embodiment of the invention in which the gas mobility reduction functional comprises four interpolation functions Fk (V k ), we define:
    - the interpolation function F 7 relating to the parameter Vi = C w s (concentration of foaming agent c w s) by a formula of the type:
    (Min (CGcr'f) T (5) and for which the constants to be calibrated are the exponent e , and the constant c w s ref which corresponds to the concentration of foaming agent under optimal reference conditions;
    - the interpolation function F 2 relating to the parameter V 2 = S W (water saturation), as defined above (see equation (4) in particular);
    - the interpolation function F 3 relating to the parameter y 3 = y 0 (oil saturation) by a formula of the type:
    F 3 = (6) where So is the oil saturation beyond which the foam loses all its faculties to reduce the mobility of the gas, and the exponent e o is a constant to be determined;
    - the interpolation function F 4 relating to the parameter V 4 = N c (linked to the gas flow rate) and 20 defined by a formula of the type:
    F 4 =
    Max (N c , Jv '.)} (7) where:
    • N c is a dimensionless number expressing the ratio between viscous forces (related to the flow of gas) and capillary forces on the local scale, which ratio can, for example, be defined according to a formula of the type n c =
    A, Mg P * gf gUt <f> S ^ wg ( C A ~ the variables involved in the calculation of N c being the porosity 0 and the gas saturation S g , the quality of the foam f g , the flow speed u t (total speed of the two phases constituting the foam), the water-gas interfacial tension a gw (which is a function of the foaming agent concentration c ”of the aqueous phase), as well as the viscosity of the gas μ. e c can be fixed a priori, for example from a physical model with lamellae, or else be subject to calibration.
    • n * c is the reference value of the capillary number N c calculated for the reference pressure gradient (equal to the minimum applied gradient VPmin for generating foam in porous medium), that is to say again for the minimum quality to generate the foam either:
    / min o g Wt N '
    According to an embodiment of the invention in which the concentration of foaming agent is invariant, the function F 4 can also be written in the following form:
    Born
    5, (/ 7) Max (Nc, N *) '
    Max sAfA sAfTA
    In general, the present invention aims to determine reliably, based on physical considerations, the parameters of a foam displacement model as a function of an optimal gas mobility reduction factor and at least an interpolation function of the optimal mobility reduction factor relative to water saturation.
    According to an implementation of the invention, the following parameters are at least determined:
    - the factor of reduction of the optimal gas mobility j / S according to equation (2);
    - the calibration constants sC. of function F 2 (equation (4)).
    According to an embodiment of the invention in which the FM functional defined in equation (2) involves the interpolation functions F ,, F 2 , F 3 and F 4 defined in equations (4) to ( 7), the foam displacement model is determined by calibrating the optimal mobility reduction factor (cf. equation (2)) and the constants of the interpolation function F 2 (i.e. the constants Θ, and sZ from equation (4)) for given parameter values of functions F ,, F 3 and F 4 , i.e. for a given foaming agent concentration, for a given oil saturation , and for a given gas flow.
    The method according to the invention comprises at least the following steps:
    1. Measurements of apparent viscosity as a function of the quality of the foam
    2. Determination of water saturation according to the quality of the foam
    3. Determination of bubble density as a function of water saturation
    4. Determination of the parameters of the foam displacement model
    5. Exploitation of hydrocarbons from the formation
    The different stages of the process according to the invention are detailed below.
    These steps are applied for a given foaming agent concentration (preferably high) and in the absence of oil, that is to say under optimal conditions ensuring optimum performance of the foam (quantified by the reduction factor of optimal mobility 1V1 mod in equation (2)). We then determine at least the optimal mobility reduction factor, as well as the calibration constants of the interpolation function relating to water saturation.
    According to an implementation of the method according to the invention, steps 1 to 3 are repeated, for example for various concentrations of foaming agent and / or for various oil saturations and / or for various gas flow rates, in order to determine in addition the constants relating to the interpolation functions relating to other parameters than water saturation, such as for example the constants involved in equations (5), (6) and (7).
    Steps 2 to 5 can be performed digitally using a computer.
    1. Measurements of apparent viscosity as a function of the quality of the foam
    During this stage, laboratory experiments are carried out in order to determine an apparent viscosity value for different values of the quality of the foam. More precisely, during this step, an injection is made, into a rock sample coming from the geological reservoir studied, of a foam for different values of quality of the foam, and a pressure drop is measured for each of the values of the quality of the foam. Then, from these pressure drop measurements, an apparent viscosity value is determined for each of the foam quality values.
    According to an implementation of the invention, the foaming agent chosen for the implementation of the invention is dissolved in an aqueous solution at a fixed concentration, of the order of g / l for example. The solution thus prepared and the gas (for example CO 2 ) are injected into the rock sample. The injections are carried out for different values of the quality of the foam. According to an implementation of the invention, the quality of the foam f g is varied at a fixed total flow rate (gas + solution), and a pressure drop is measured (ie pressure difference between upstream and downstream of the rock sample considered) for each quality value of the foam f. From the pressure drop measurements, we g
    determines, for each of the values of the quality of the foam f, a viscosity g
    apparent μ νρ of the foam according to a formula of the type:
    _kNP
    Rapp ~
    Ut where VP
    ΔΡ
    L is the pressure gradient measured in steady state flow through the sample of porous medium for a given value of the quality of the foam f, L is the length of the rock sample considered, ΔΡ is the loss load g
    measured between the upstream and downstream of this sample for the considered value of the quality of the foam f, Ut is the total speed (gas + solution) and k is the permeability of g
    the rock sample taken.
    2. Determination of water saturation as a function of foam quality
    During this step, it is a question of determining a water saturation value for each value of the quality of the foam for which a measurement of the apparent viscosity has been carried out (cf. previous step). This step requires having permeability measurements relating to the aqueous phase k (Sw), which are invariant whether the foam is present or absent. It is well known that these measurements are distributed along a curve known as the relative permeability curve. According to an embodiment of the invention, instead of carrying out relative permeability measurements in order to determine a relative permeability curve, use is made of already pre-established curves, such as the curves defined analytically (by power functions ) in the document (Lotfollahi et al., 2016).
    According to the invention, the water saturation S w of the porous medium under steady flow of foam is determined by inversion of the curve k (Sw). Thus, according to this mode of implementation, the water saturation S w is determined according to a formula of the type:
    (θ) fo-zp / '- j
    According to an embodiment of the invention, the relative permeability curves are represented analytically by power functions of the normalized saturation. The permeability curve relating to water can for example be written in the form:
    (9)
    wi û gr
    5 gr are the minimum saturations of water and gas respectively, is the exponent of water permeability, and £ wmax is the maximum value of the water permeability. Similarly, by way of example, the permeability curve relating to the gas k rg can be written as a function of 5 ^, that is:
    (10) ° ù krgmaxOst the maximum value of the gas permeability. We can then deduce the normalized water saturation according to a formula of the type:
    nvma;
    (11) where f w = 1- f g , p w is the viscosity of water, and μ αρρ is the apparent viscosity, as determined in the previous step, for a given value of the quality of the foam f . We g
    can then obtain the water and gas saturations for each value of the quality of the foam f according to formulas of the type:
    g
    (12)
    (13)
    Thus, at the end of this step, at least one water saturation value is obtained for each quality value of the foam.
    3. Determination of bubble density
    During this step, using a lamella model as a function of water saturation, and permeability measurements relating to the aqueous phase and to the gas, a density of lamellae (or texture) is determined for each of the values of the quality of the foam. Lamella models predict the effects of foam in terms of reduced mobility and also describe the mechanisms of generation and distribution of lamellae in porous media. In particular, the texture is a physical quantity representative of the capacity of the foam to reduce the mobility of the gas.
    According to one embodiment of the invention, the lamella model consists of a law of evolution of the viscosity of the gas μ 9 flowing in the form of foam as a function of the (14) density of lamellae (or texture of foam) ty of the form:
    where v g is the local or interstitial speed (intra-pore) of the gas phase in discontinuous form within the foam, μ 8 the speed of the gas phase in continuous form, and
    C f a constant for the rock-fluids system considered. This rheological law of the gas flowing in the form of bubbles is notably described in the documents (Bretherton, 1961) and (Hirasaki and Lawson, 1985) which relate to the flows of one or more bubbles within capillary tubes.
    Such a lamella model makes it possible to link the saturation (characteristic parameter of multiphase flow in porous media) to the texture (characteristic parameter of the foam). The relationship between these characteristic parameters is obtained by writing the ratio of the filtration flow rates of the two phases, that is, knowing that u g = f g u t and u w = G ~ f g } u t :
    A g + 1/3
    1/3 (15)
    According to an embodiment of the invention according to which the relative permeability curves are modeled as power functions of the normalized saturation as described in equations (9) and (10), one can rewrite equation (15) as follows :
    Then, from equation (16), we deduce:
    C f n f -
    (17), with s g = t ~ S w We thus obtain an expression of the texture nf which depends on the water saturation. In this way, for any value of the quality of the foam, it is possible to assign a value of the texture nf (to the value of the constant Cf close) as a function of a single value of saturation. Thus, this step leads to the transcription of the experimental information into a law connecting the number of lamellae nf and the water saturation S w deduced from the flow measurements of the foam considered in the porous medium considered for different values of the quality foam.
    According to an implementation of the invention, a normalized texture nf is also determined, namely nf -——, which can also be written in the following manner:
    Tl f max
    See nf
    MaxiCf n f i = , n KJJ 'i (18)
    The values (C / R /). i = t 2, ..., n (n = number of foam quality values) are calculated as explained in the previous step. C f is a constant that can be estimated from the maximum value of the product Cfn f , equal to Cfn fm! A , where " / max is the maximum texture estimated as the inverse of the characteristic volume of foam bubbles, which volume is calculated from the characteristic threshold radius between pores of the medium studied. This threshold radius can be formulated as
    according to the simplified representation of a porous medium of porosity 0 and of permeability k as an assembly of capillaries.
    4. Determination of the parameters of the foam displacement model
    During this step, it is a question, on the basis of the lamella model as described in the previous step and of the permeability measurements relating to the gas and to the aqueous phase, of determining the parameters of a displacement model of the foam is a function of at least one factor for reducing the optimal mobility of the gas and a function of interpolation of the factor for reducing the optimal mobility relative to the water saturation (cf. equations (1), (2), ( 3) and (4)).
    According to an embodiment of the invention in which the function of interpolation of the displacement model of the foam relating to the water saturation is written according to equation (4), the parameters of the displacement model are determined as follows :
    - Determination of, < *,:
    As established in the previous step, the texture is solely a function of the water saturation. Furthermore, from a physical point of view, it is well known that there is a critical water saturation Sw below which the foam bubbles fuse (coalescing), that is to say that the normalized texture drops rapidly from 1 to 0.
    According to an implementation of the invention, the critical saturation sZ is defined by the water saturation for a normalized texture equal to 0.5 (median normalized texture value), ie:
    S * w = nf - 0.5 ·) (19) where nf 1 is the inverse of the normalized texture nf (cf. previous step).
    Thus, the constant sZ> involved in the equation of the interpolation function F 2 as defined in equation (4), can be determined directly from the texture nf , itself determined directly from measurements experimental (see steps 1 and 2 described above).
    • Determination of (f
    The constant (f which appears in the expression of the interpolation function F 2 as described in equation (4), makes it possible to transcribe the more or less rapid transition of the normalized texture from 0 to 1 when the saturation in water increases (or even when the gas saturation decreases) In addition, from a physical point of view, we can observe that the foam disappears, ie that the normalized texture nf vanishes, for a water saturation 5 wmin lower at the critical saturation sÇ, but nevertheless in the vicinity of the critical saturation sZ In addition, the experimental data make it possible to determine a representative function of the texture nf (to within a multiplicative constant) and the corresponding saturation for various values of the quality of the foam f. However, g
    very high quality measurements such as texture nf tends towards 0 are not accessible (or reliable).
    According to an implementation of the invention, the constant / , is defined according to a formula of the type:
    θ „> - (20)
    5 * wopt 5 * w where s wop , is the water saturation which maximizes the apparent viscosity (or texture) of the foam, and beyond which the latter decreases until it reaches the viscosity of the continuous gas phase ( corresponding to n / = 0).
    Preferably, the constant is defined as included in the following interval:
    5 * wopt S w <0 <- (7 w -
    100
    5 * wopt S w (21) • Determination of the optimal mobility reduction factor m% a
    From a physical point of view, the mobility of the gas decreases when the quality of the foam increases between a minimum value and a value f opl , called optimal foam quality, beyond which the foam degrades.
    According to an implementation of the invention in which the lamella model is defined according to equation (14), it can be shown that the mobility reduction factor of the gas is expressed according to a formula of the type:
    opi mod
    Cf fî max // (minA 1/3 (22)
    This expression of the optimal mobility reduction factor (ie maximum) is consistent with physics, namely that it is maximized for a density of lamellae (or foam texture) equal to the maximum density n fmax and the minimum speed at which such foam can be generated.
    Thus, at the end of this step, there are values of the parameters involved in a model of displacement of the foam as a function of a factor of reduction of mobility of the optimal gas and at least of an interpolation function of the factor of optimal mobility reduction relative to water saturation.
    According to an implementation of the invention in which the foam displacement model involves at least one other interpolation function F k than that depending on the water saturation, steps 1 to 3 are repeated as described below. above for different values of the parameter Vk of an interpolation function Fk, and the constants specific to this other interpolation function are determined, from the optimal mobility reduction factor as determined at the end of the step 4 described above and a mobility reduction factor relating to the interpolation function considered. According to an implementation of the invention, the optimal mobility reduction factor Λ / Ld associated with the parameter Vk of an interpolation function Fk can be written according to a formula of the type:
    F k (V k )
    MLd-1
    4Æ-1 (23) ° ù / WX, is the optimal mobility reduction factor determined at the end of step 4 as described above.
    By way of illustration, the determination of the constants of the function F 7 as described in equation (5), relating to the concentration of foaming agent in the foam, can be broken down as follows:
    - We define a plurality of key values of concentration of the foaming agent in the aqueous phase constituting the foam studied. According to an implementation of the invention, a maximum value cT ref is defined (for example beyond which the process is clearly no longer economical) and a predetermined number of intermediate values between 0 and this maximum value;
    - For each of the concentration values thus chosen, the measurements of the apparent viscosity of the foam are repeated as a function of the quality of the foam as described in step 1, that is to say that injections are carried out at fixed total flow and fixed concentration for different values of the quality of the foam;
    - Steps 2 and 3 are then applied as described above to the apparent viscosity measurements thus obtained, that is to say that the water saturations are determined as a function of the quality of the foam as described in step 2 above, then the corresponding bubble densities, for example by calculating the values of C f n f as a function of the quality f g as described in step 3 above. Knowing that the value of the maximum texture “ / max is invariant for a given porous medium, the maximum value of the product C f n f makes it possible to determine a new value of Gqui which reflects the impact of the concentration on the performance of the foam.
    - it is then determined, for example by means of equation (22), a mobility reduction factor Mk associated with the interpolation function F to each of the foaming agent concentration values c · From the values of AfLd For the different foaming agent concentration values c and the optimal mobility reduction factor m'Î as determined at the end of step 4, the exponent e s is then determined allowing the curve described to be best calibrated by a formula of the type (and deduced directly from the equations (23) and (5)):
    Minod
    w;, cr ^) V * ç w-ref (24)
    According to an implementation of the invention according to which the foam displacement model involves at least two other interpolation functions than that depending on the water saturation, the constants associated with these other functions d are determined. interpolation as described above, sequentially, interpolation function by interpolation function.
    5. Exploitation of hydrocarbons from the formation
    During this stage, it is a question of determining at least one exploitation diagram of the hydrocarbons contained in the formation. In general, an operating diagram includes a number, a geometry and a location (position and spacing) of the injector and producer wells. But an oil exploitation plan also includes the definition of a type of enhanced recovery. In the case of enhanced recovery of hydrocarbons by injection of a gas in the form of foam, the operating scheme can also be defined by a type of gas injected in the formation studied and / or by the type of foaming agent added to this gas, by the amount of foaming agent etc. An operating plan for a hydrocarbon reservoir should, for example, allow a high rate of recovery of hydrocarbons trapped in the geological reservoir, over a long operating period, and requiring a limited number of wells.
    According to the invention, the determination of the hydrocarbon exploitation scheme of the formation is carried out using a flow simulation exploiting the foam displacement model established during the previous steps. An example of a flow simulator (also called a tank simulator) allowing the consideration of a foam displacement model is the PumaFlow software (IFP Energies nouvelles, France). According to the invention, at any time t of the simulation, the flow simulator solves all of the flow equations specific to each cell and delivers solution values of the unknowns (saturations, pressures, concentrations, temperature, etc. ) predicted at this time t. From this resolution, comes the knowledge of the quantities of oil produced and the state of the deposit (distribution of pressures, saturations, etc.) at the instant considered. According to one embodiment of the invention, different operating patterns of the fluid of the formation studied are defined and it is estimated, using the flow simulator integrating the foam displacement model determined with the resulting from step 3, for example the quantity of hydrocarbons produced according to each of the different operating patterns, the curve representative of the evolution of production over time at each well, etc.
    Then, once the exploitation scheme has been defined, the hydrocarbons trapped in the formation are exploited according to this exploitation scheme, in particular by drilling the injector wells and producers of the exploitation scheme thus determined, so as to produce the hydrocarbons , and by installing the production infrastructure necessary for the development of the deposit.
    It is understood that the exploitation scheme can be evolving over the duration of an exploitation of a geological reservoir, as a function of the knowledge relating to the reservoir acquired during exploitation, improvements in the various technical fields occurring during the exploitation of a hydrocarbon deposit (improvements in the field of drilling, assisted recovery for example).
    Example of realization
    The characteristics and advantages of the process according to the invention will appear more clearly on reading the example of application below.
    More specifically, the present invention has been applied to the measurements of one of the tests described in the document (Alvarez et al., 2001). The test was carried out on a sandstone rock, representative of a reservoir in which hydrocarbons would be trapped and from which samples were taken by coring.
    The enhanced recovery of liquid hydrocarbons from such a reservoir is simulated experimentally by displacement of a gas (nitrogen in this case) injected in the form of foam formed by mixing this gas with an aqueous phase containing a foaming agent ( anionic surfactant in the present case) at a concentration of 1% by weight.
    For this example of implementation, we use analytical functions of permeabilities relating to gas and water predetermined for this type of rock (in this case a sandstone) and described in the literature, as for example in the document (Lotfollahi et al., 2016).
    The characteristics of the rock-fluid-foam system relating to these measurements are presented in Table 1.
    Table 1
    Porosity (%) 0.18 Permeability (mD) 530 Viscosity of the gas μ α (1 mPa-s.) 0.02 Viscosity of water ju w (1 mPa-s.) 0.7 Maximum gas permeability k rgmax 0.94 Maximum water permeability k mmax 0.2 Exponent w of the curve k m 4.2 Exponent g of the curve k rg 1.3 Minimum water saturation S wi 0.2 Minimum gas saturation S gr 0.2 Î8FEstimated foam bubble radius - (m)V 4.82176E-06 Maximum texture n fmax (m 3 ) 2.12958E + 15 Gas flow speed + solution u t (m / s) 8.81944E-06
    Pressure drop measurements at total speed u t fixed, as described in step 1 of the present invention, are carried out for foam quality values varying between 0.25 and 0.90. Apparent viscosity values are determined from these pressure drop measurements for each of the foam quality values. These apparent viscosity values are presented in the first two lines of Table 2.
    Table 2
    fg 0.25 0.30 0.37 0.45 0.50 0.60 0.67 0.76 0.80 0.86 0.90 Fapp, Cp 550 600 660 730 760 830 870 920 800 600 400 Sw 0.368 0.362 0.354 0.346 0.341 0.331 0.324 0.313 0.312 0.310 0.312 Cfüf, Pa.s. (m / s) 1/3 0.0362 0.0355 0.0346 0.0343 0.0336 0.0333 0.0330 0.0328 0.0276 0.0198 0.0128 n f / n fmax 1,000 0.981 0.955 0.946 0.928 0.919 0.910 0.905 0.763 0.547 0.353
    From these values of apparent viscosity, the water saturation Sw and the texture for each of the quality values of the foam are determined, by proceeding in the manner described in steps 2 and 3 of the present invention. The results of these steps are presented in the last three rows of Table 2, as well as in Figures 1 and
    2. In particular Figure 1 shows the evolution of saturation (Sw) and the evolution of the normalized texture (nf / nfmax) as a function of the quality of the foam (fg). Figure 2 presents the evolution of the normalized texture (nf / nfmax) as a function of the water saturation (Sw).
    It is thus observed that the texture of the foam remains almost constant over a large quality interval ranging from 0.25 to 0.75 approximately, and that beyond, for higher qualities ranging from 0.76 to 0.9, the texture of the foam decreases rapidly , which translates effectively the decrease in the apparent viscosity of the foam from 920 to 400 cp. The quality of f gopt foam which maximizes the apparent viscosity of the foam is therefore equal to 0.76 in the present case. At the same time, it can be seen that the water saturation varies little over the entire range of foam quality explored by these measurements. Figure 2 thus shows, in addition to Figure 1, that the texture of the foam can vary considerably without the water saturation of the porous medium being considerably modified.
    These results illustrate the fact that the reduction in mobility of the gas injected in the form of foam (reduction in mobility measured by the apparent viscosity) is much more sensitive to the texture of the foam (number of bubbles or lamellae) than saturation of the porous medium: in other words, the performance of a foam in porous medium is more easily modeled (ie the calibration of the model easier) via the intermediate texture variable than via the only saturation variable. The advantage of using a lamella model as an intermediary to calibrate the foam displacement models from experimental data is thus demonstrated.
    From the texture values thus determined, the values of the parameters involved in the foam displacement model are determined, as described above in step 4, as a function of at least one factor for reducing the optimal mobility of the gas, and an interpolation function of the optimal mobility reduction factor relative to water saturation (see equations (1), (2), (3) and (4)). The values of these parameters are as follows:
    - optimal gas mobility reduction factor aÆ : 67,500;
    - critical saturation ^: 0.31
    - constant Q v : greater than or equal to 10 / (0.368-0.310) = 175, and preferably between 10 / (0.368-0.310) = 175 and 100 / (0.368-0.310) = 1750.
    The value of S w * thus obtained, from apparent viscosity measurements and from a physical model of the lamella model type, is the same as that obtained by numerical adjustments as described in the document (Lotfollahi et al. 2016 ). The value determined for the mobility reduction factor A / X, is also of the same order of magnitude as those obtained by numerical adjustment (by iterative least squares method) of the foam models of other known simulators, such as UT and STARS. referenced by Lotfollahi et al. (2016) on the modeling of these same tests.
    Thus, the method according to the invention allows a parametrization of a model of displacement of the foam from experimental data interpreted according to a model representative of the physics of the foam (assembly of bubbles). Using a physical lamella model as an intermediary to calibrate the foam model ensures a calibration of the physically valid foam displacement model.
    权利要求:
    Claims (6)
    [1" id="c-fr-0001]
    1. Method of operating an underground formation comprising hydrocarbons, by means of an injection of an aqueous solution comprising a gas in the form of foam and of a flow simulator based on a displacement model of said gas under form of foam, said displacement model being a function of an optimal mobility reduction factor of said gas and at least one interpolation function of said optimal mobility reduction factor, said interpolation function being a function of at least the water saturation and at least one constant, characterized in that, from at least one sample of said formation, and from measurements of conventional relative permeability to the aqueous phase and of measurements of conventional relative permeability to gas:
    A. determining at least said mobility reduction factor of said optimal gas and said constant of said interpolation function according to at least the following steps:
    i. an injection is carried out at constant total speed into said sample of said gas in the form of foam for a plurality of values of the quality of the foam, and an apparent viscosity is measured for each of said values of the quality of the foam;
    ii. from said conventional relative permeability measurements and said apparent viscosity measurements for the plurality of foam quality values, a water saturation is determined for each of said foam quality values;
    iii. from a lamella model as a function of said water saturation and said conventional relative permeability measurements of gas and said aqueous phase, a value of the texture of the foam is determined for each of said values the quality of the foam;
    iv. from said texture values, at least said mobility reduction factor of said optimal gas and said constant of said interpolation function of said optimal mobility reduction factor are determined;
    B- from said displacement model and from said flow simulator, an optimal exploitation scheme for said deposit is determined and said hydrocarbons are exploited.
    [2" id="c-fr-0002]
    2. The method of claim 1, wherein said apparent viscosity relative to a value of the quality of the foam is determined from a pressure drop measurement in said sample for said value of the quality of the foam.
    [3" id="c-fr-0003]
    3. Method according to one of the preceding claims, in which said lamella model consists of a function relating the texture of the nf foam to the water saturation s v according to a formula of the type:
    Cfti f —a w
    Zrwmax Ç w
    <f V / 3 J gu,
    7Γ where “is the quality of the foam, p w the viscosity of the aqueous phase, μ β the speed of the gas phase in continuous form, Ut is the total speed of the gas and the solution, C f a constant for the system rock-fluids considered, ^ ™ ma x es t | a maximum value of the permeability relative to water, £ ,,, niax is the maximum value of the permeability relative to gas, s g is the gas saturation, φ is the porosity, a „is the exponent of the function power representative of said permeability measurements relating to water, and a, is the exponent of the power function representative of said permeability measurements relating to gas, and S w is the normalized water saturation.
    [4" id="c-fr-0004]
    4. Method according to one of the preceding claims, in which said foam displacement model is additionally a function of at least one interpolation function F k depending on a parameter Vk different from the water saturation, and in which prior to step B) and for each of said interpolation functions F k , steps i) to iii) are repeated for different values of the parameter Vk of said interpolation function F k , and the constants relating to said interpolation function F k from said optimal mobility reduction factor and a mobility reduction factor relating to said interpolation function F k .
    [5" id="c-fr-0005]
    5. The method of claim 5, wherein said parameter Vk is chosen from a concentration of foaming agent, oil saturation, and a gas flow rate.
    [6" id="c-fr-0006]
    6. Method according to one of claims 5 to 6, in which said mobility reduction factor M k mOd relating to the function F k is written according to a formula of the type:
    FdVÙ
    MLd-1
    AiS-l or opt mod is said to be the optimal mobility reduction factor.
    1/1
    0.75
    0.5
    0.25
     1  1 u ♦ s not wf / nfmax ♦ ♦> 1 < ► ♦
    fg
    0.2 0.4 0.6 0.8
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    同族专利:
    公开号 | 公开日
    FR3062672B1|2019-07-05|
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    MX2018001294A|2018-11-09|
    US20180223638A1|2018-08-09|
    EP3358129A1|2018-08-08|
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    EP3763913A1|2019-07-12|2021-01-13|IFP Energies nouvelles|Method for operating a hydrocarbon reservoir by injecting a gas in foam form|
    CN111236899A|2020-01-14|2020-06-05|西南石油大学|Gas cap oil reservoir development seepage testing method|
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    优先权:
    申请号 | 申请日 | 专利标题
    FR1750940|2017-02-03|
    FR1750940A|FR3062672B1|2017-02-03|2017-02-03|METHOD FOR OPERATING A HYDROCARBON STORAGE BY INJECTING A GAS IN THE FORM OF FOAM|FR1750940A| FR3062672B1|2017-02-03|2017-02-03|METHOD FOR OPERATING A HYDROCARBON STORAGE BY INJECTING A GAS IN THE FORM OF FOAM|
    EP18305032.7A| EP3358129A1|2017-02-03|2018-01-16|Method for operating a hydrocarbon reservoir by injecting a gas in foam form|
    MX2018001294A| MX2018001294A|2017-02-03|2018-01-30|Method for developing a hydrocarbon reservoir by injecting a gas in the form of foam.|
    CA2993549A| CA2993549A1|2017-02-03|2018-01-30|Production process for a hydrocarbon deposit by injecting a gas in the form of a foam|
    US15/887,498| US10830026B2|2017-02-03|2018-02-02|Method for developing a hydrocarbon reservoir by injecting a gas in the form of foam|
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