EA042218B1 - PRODUCTION WATER DISTRIBUTION OPTIMIZER TOOL - Google Patents

Description

Technical field

SUBSTANCE: invention relates to means for optimizing formation water distribution for dynamic distribution of formation water (PW) during enhanced oil recovery (EOR) with low-salinity or softened water flooding, and to systems and methods using such a tool. In particular, the present invention relates to a means for optimizing the distribution of formation water while maintaining the EOR, ensuring the disposal of the entire volume of IW using disposal procedures with or without re-injection. More specifically, this invention relates to a means for optimizing the injection of HP and brackish or softened water into a reservoir, provided that all HP is utilized, while maintaining increased oil recovery in one or more segments of this reservoir.

State of the art

When hydrocarbons are extracted, water is often also extracted along with hydrocarbon components. This produced formation/production water (hereinafter - formation water) often has a high salinity and may also contain other dissolved components that make it unsuitable for reuse as an injection fluid for EOR due to fouling of the membranes used to obtain such fluid for EOR. PNO. Dissolved HP components can be toxic and difficult to separate, making disposal of HP difficult and uneconomical. In the recovery and disposal of HP during oil production, additional difficulties may arise when the reinjection of such fluids interferes with the required production technology.

The essence of the invention

The present invention discloses a method for dynamically distributing total formation water (TW) from a reservoir during enhanced oil recovery (EOR) using brackish or softened water flooding for the EOR, which: obtains measurement data associated with the reservoir, the RW and the brackish or softened water, and includes: the flow rate of the withdrawal of HP from the productive formation, the flow rate during injection of brackish or softened water, the range of composition of the injected water, and the total flow rate of water injection; receive information about the parameters of the reservoir, including: one or more zones of injection of FOR, injection rate at FOR associated with each of one or more injection zones of FOR, one or more zones of utilization injection, injection rate in the zone of utilization injection associated with each of one or more disposal injection zones, one or more disposal procedures without re-injection, and a disposal rate without re-injection associated with each of the one or more disposal procedures without re-injection; determining a mixing flow rate comprising at least a portion of the current HP withdrawal flow rate and at least a portion of the brackish or softened water injection flow rate to obtain a mixed injection fluid, wherein the mixing flow rate maintains the composition of the mixed injection fluid in the injection water composition range; mixing at least a portion of the HP with at least a portion of brackish or softened water at this mixing rate; and dynamically allocate the HP withdrawal rate between: (a) re-injection into the reservoir with mixing with brackish or softened water and injection into one or more injection zones for EOR, injection into one or more disposal injection zones, or a combination thereof; (b) disposal through one or more disposal procedures without re-injection, or a combination of them, where dynamic allocation maintains the injection rate for the EOR, the injection rate in the disposal zone, and the disposal rate without re-injection below the specified thresholds, ensures that the entire recovery rate of the IW is recovered through re-injection or no re-injection, and provides a total void replacement rate when the total amount of water pumped back into (a) is equal to that required to replace the voids.

Also disclosed is a system for dynamically distributing produced water (PW) for disposal in a reservoir during waterflooding with brackish water, including: a storage device storing a dynamic distribution means; a processor in communication with the storage device, wherein the dynamic allocation means, when executed by the processor, configures the processor to: receive reservoir data containing a determination of the allocation of one or more reservoir segments as disposal segments and one or more reservoir segments as segments for waterflooding, and total withdrawal costs of IW; introducing into the dynamic distribution engine data containing the distribution of one or more reservoir segments and the total withdrawal costs of the IW; preliminary (qualitative) assessment of the features of enhanced oil recovery (EOR) with low-salinity water flooding by segments for each of one or more segments and the total enhanced oil recovery; numerical evaluation of various procedures and costs of disposal of HP with and without re-injection; and determining, based on preliminary and numerical evaluations, one or more IW routes comprising: one or more re-injection routes selected from (a) mixing with a brackish flow produced by a brackish water treatment plant

- 1 042218 with saline water, for injection into one or more segments of the water treatment plant with low-salinity water flooding; (b) reinjection as reclaimed water into one or more of the segments for disposal; or a combination of these routes, and/or one or more non-reinjection routes containing (c) a diversion as part of the produced oil; (d) discharge, or combinations of these routes, when the costs of disposal of HP through (a), (b), (c), (d) or their combinations are equal to the total cost of extraction of HP.

Also described in the present disclosure is a system for simultaneously injecting brackish water flooding and formation water for disposal in a reservoir having multiple segments, including: a brackish water preparation system adapted to generate a brackish water stream; a separator adapted to separate the shipped commercial oil from the field product containing the produced oil, the total amount of HP for disposal and gas; a brackish water injection manifold communicating (having a fluid connection) via a brackish water line with the brackish water preparation system; a disposal discharge manifold having fluid connection via a disposal line with a separator; one or more injection pumps in fluid communication with the brackish water injection manifold and the disposal injection manifold; a brackish water injection manifold in fluid communication with one or more injection pumps, whereby a brackish water treatment stream, containing at least a portion of the brackish water stream, can be injected into one or more reservoir segments dedicated to the water treatment plant with brackish waterflooding ; a disposal injection manifold in fluid communication with one or more injection pumps, whereby a disposal stream containing at least a portion of the total HP for disposal can be pumped into one or more reservoir segments allocated for disposal; a mixing line fluidly connecting the disposal line to the brackish water line, whereby a portion of the entire HP for disposal can be mixed with the brackish water stream to produce a brackish POR stream before it is fed to the brackish water manifold; and a control system comprising a processor with software tools (PS) configured to: determine injection rates per segment in accordance with the requirements for void replacement and injection for EOR, with dynamic allocation of all HP for disposal through one or more reinjection routes, one or more routes without re-injection; and combinations thereof, wherein the one or more re-injection routes are selected from injection into a recovery injection manifold through a disposal line, injection into a reservoir of low-salinity water through a mixing line, or a combination of these routes.

While a number of embodiments are disclosed herein, other embodiments will be apparent to those skilled in the art upon reading the detailed description below. It will be understood that some of the embodiments disclosed herein may be modified in their various aspects within the spirit and scope of the claims presented herein. Accordingly, the following detailed description should be considered as a specific example and not limiting the invention.

Brief description of the drawings

The following figures illustrate embodiments of the subject matter disclosed herein. An understanding of the claimed subject matter may be gained by considering the foregoing description with reference to the accompanying drawings, in which:

in fig. 1 is a flowchart of method 1 for dynamically distributing total formation water extracted from a reservoir during an enhanced oil recovery process using low-salinity or softened water EOR flooding, in accordance with an embodiment of the present invention;

in fig. 2 is a diagram I of a field facility in which the ROI optimizer disclosed herein can be used to allocate ROI utilization, in accordance with an embodiment of the invention;

in fig. 3 shows scheme II of a field facility in which the ROI optimizer disclosed herein can be used to allocate ROI utilization, in accordance with another embodiment of the invention;

in fig. 4 is a block diagram of a system III for dynamic distribution of HP for disposal in a reservoir during a brackish water flooding process, in accordance with an embodiment of the present invention.

Detailed description of the invention

As used herein, the term membrane refers to microfiltration (MF), ultrafiltration (UF), reverse osmosis (RO), or nanofiltration (NF) elements. Technically, MF/UV elements can be thought of as filters, but for simplicity they are referred to here as membranes.

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Low-mineralized water is water obtained by removing at least part of the salts (eg NaCl) or other dissolved solids from the highly mineralized feed water or HP. In the present disclosure, brackish water can be water having a salinity or total dissolved solids content (TSDS) of less than 8000, 9000 or

10000 ppm (parts per million).

Softened water is water obtained by removing at least some of the hardness ions (eg, multivalent cations, including magnesium and calcium) from highly mineralized feed water or HP. As used herein, softened water may be water having a hardness (expressed in grains per gallon (or ppm) as calcium carbonate equivalent) less than or equal to about 1 grain per gallon (g/gal) or 17.0 ppm (mg/L ).

The highly mineralized feed water or feed water is the feed water for the demineralization or softening plant, which is usually sea water (MB), estuary water, aquifer water or mixtures thereof in the demineralization plant, but in the case of a water softening plant, it may be formation water or may also contain this water.

Module (unit) ultrafiltration (UF) contains a pressure vessel containing one or more UV elements, for example from 1 to 8 membrane elements, or from 4 to 8 UV membrane elements.

The reverse osmosis (RO) filtration module comprises a high pressure vessel or housing containing one or more RO membrane elements, for example 1 to 8, or 4 to 8 RO membrane elements.

The nanofiltration (NF) module contains a pressure vessel containing one or more NF elements, preferably 1 to 8 membrane elements, or 4 to 8 NF membrane elements.

A reverse osmosis (RO) stage or unit of a demineralization plant is a group of RO filtration modules connected in parallel to each other. Similarly, a nanofiltration (NF) stage or demineralization plant assembly is a group of NF filtration modules connected in parallel to each other.

Relic water is water present in the pore space of the oil-bearing layer of the reservoir.

An aqueous working fluid or working fluid is an aqueous fluid that can be injected into an injection well after injecting a plug (slug) of a small pore volume (PV) of low-mineralized or softened injection water PNO.

Plug (rim) is a low pore volume of fluid injected into the oil-bearing layer of the reservoir. The pore volume values for brackish injection water plugs are based on the swept pore volume PVR (pore volume ratio) of the formation rock layer(s).

TSPTS is the total content of dissolved solids in the water stream, usually expressed in mg/l.

The unit of ppmv is parts per million by volume, which is equivalent to the unit mg/l. In the present description, unless otherwise indicated, ppm means ppmv.

Enhanced oil recovery (EOR) using brackish or softened water floods has the problem of disposing significant amounts of HP, particularly when there are legal restrictions on overboard discharges and/or when the cost and time of obtaining overboard permits become excessive.

As a result of water demineralization or softening, water with a salinity lower than optimal for continuous injection into the oil reservoir can be obtained. Indeed, demineralized or softened water can damage the reservoir horizon and can inhibit oil production, for example by causing clays to swell and slump so as to plug the reservoir formation. At the same time, there is an optimal salinity for the injected water, which favorably provides increased oil recovery and at the same time reduces the risk of deterioration of the reservoir properties of the formation, and this optimal salinity value can vary within one productive formation due to a spatial change in the composition of the rock along the productive formation (as in vertically and transversely). As a general rule, when an oil reservoir rock contains a large amount of swellable clays, deterioration of reservoir properties with continued oil recovery can be avoided if the injected water has a total dissolved solids content (TSDS) in the range from 200 to 10,000 parts per million (ppm) , and the ratio of the concentration of polyvalent cations in low-mineralized injected water to the concentration of multivalent cations in the relict water of the reservoir is less than 1, for example, less than 0.9.

Produced water utilization may then include reinjection into the reservoir as a component of a composite stream containing brackish or softened water and some formation water suitable for obtaining a composite stream of brackish or softened FOR water having a given or target salinity, or TWR, for

- 3 042218 for enhanced oil recovery (EOR). Since the amount of formation water and its composition will change in different stages of FOR from a reservoir, there is a need for systems, methods and means for dynamically distributing the recovery of HP during waterflooding with brackish or softened water.

The present disclosure relates to a tool that can be implemented as a software tool (WP), and a module, application, etc., for evaluating various ways of utilizing formation water (PW) when injecting brackish injection water and / or softened water into a reservoir for enhanced oil recovery (EOR), and the system and method using this tool. The PW optimization tool disclosed herein determines the optimal ratio between the pore injection rate (total water demand), the formation water re-injection rate (RWR) and the low-salinity and/or softened water injection rate (equal to the difference between the pore replacement rate and the RWR rate), and ensures that all produced water is distributed to various disposal procedures by means of re-injection and without the use of re-injection. Because the amount of HP to be disposed of in a reservoir and its composition will constantly change, typically increasing over time, the dynamic allocation of the present disclosure can manage the utilization of varying amounts of HP in a FOR process using brackish or softened water flooding.

In embodiments, the facility was used for short-term dynamic allocations of PV. In embodiments, the tool is primarily a predictive tool that provides long-term predictive planning or forecasting of possible options for the utilization of produced water that may be selected in the future. By evaluating the impact of the selected option on the utilization of produced water, and hence on production from EOR, this tool may, in embodiments, enable the user to test alternative options and make informed decisions. In embodiments, the tool disclosed herein is for long-term forecasting (e.g., years) to understand the impact of field development decisions over the long term (including, but not limited to, where and when to drill wells, which segments to use for disposal of IW depending on injection for PNO, etc.). In embodiments, the tool is an extension of the simulation model traditionally used by the field management team as a long-term forecasting and decision making tool.

The following is a description of the method of the present invention with reference to FIG. 1 illustrating a flowchart of method 1 for dynamically distributing total formation water from a reservoir during enhanced oil recovery using brackish or softened water flooding for EOR. The method includes obtaining measurement data associated with the reservoir, IW and brackish or softened water (step 1A), obtaining data on the characteristics of the reservoir (step 1B), determining the mixing flow rate, containing at least a portion of the flow rate of selection of IW and, according to at least a portion of the brackish or softened water injection flow to obtain a mixed injection fluid (step 1C), mixing at least a portion of the HP with at least a portion of the brackish or softened water at a mixing rate (step 1D), and dynamic distribution of the total amount of HP between different disposal procedures with and without re-injection (step 1E). It should be understood that while the measurement data reference is associated with the reservoir, the received measurement data may include actual data, simulation data, calculated/predicted data (e.g., from a computational reservoir model), or combinations thereof associated with the reservoir. Dynamic distributions may use actual data and/or simulation data, while long-term forecasts may use predictive data and/or simulation data (eg, predictive data may be simulated). In addition, it should be understood that in embodiments, in addition to HP, other highly mineralized water (for example, sea water) can be used to prepare a mixed injection fluid, and HP is disposed of by procedures other than mixing with at least part of the low-mineralized or softened water. The means disclosed herein also allows for disposal of HP in the embodiments and other procedures mentioned herein (e.g., discharge overboard, pumping into a dedicated HP injection well, etc.) where mixing of HP with at least a portion of brackish or softened water to obtain injection fluid for PNO is practically absent.

Method 1 includes obtaining measurement data (eg, actual, calculated/predicted data, and/or simulation data, as mentioned above) associated with the reservoir, IW, and brackish or softened water (step 1A). These measurements may include the recovery rate of IW from the reservoir, the rate of injection of low-salinity or softened water for the EOR, the specified range of the composition of the injected water for the EOR, the total water injection rate, the salinity of the IW, or a combination of all these data.

Method 1 also includes obtaining information about the reservoir parameters (step 1B). Formation parameter information may include: identifying one or more reservoir zones or sections as FOR injection zones, FOR injection rate associated with each of one or more FOR injection zones, identifying one or more reservoir zones or sections. formation as one or more disposal zones, an injection rate to the disposal zone associated with each of the one or more disposal zones, information regarding one or more possible disposal procedures without re-injection, and a utilization rate without re-injection associated with each from one or more disposal procedures without re-injection. For example, the tool, system, or method disclosed herein can be used with any reservoir, or with any reservoir that can be divided into sections, segments, or zones (e.g., separated physically, or imaginary or virtual) to inject a brackish water plug or softened water in the secondary production mode, followed by the injection of formation water, brackish water or softened water in the tertiary production mode after formation water injection, or for disposal of IW. The tool can be used to test for weaknesses and to develop a plan of action, and may lead to the development of an alternative injection/disposal plan, and possibly affect the development of the field (for example, a reservoir) in terms of the number of injections into each section or zone of the reservoir, size of pumps/manifolds, etc. In an embodiment, an analysis using the tool disclosed herein is used to develop designs for EOR waterflooding equipment.

Method 1 also includes determining a mixing flow comprising at least a portion of the HP withdrawal flow and at least a portion of the brackish or softened water injection flow to obtain a mixed injection fluid (step 1C). The mixing flow rate may be selected to maintain the composition of the mixed injection fluid in the range of the injection water composition for the EOR. Formulations within a given operating range for a segment or area of a reservoir are those formulations that are predicted to achieve enhanced oil recovery (EOR) from each area of the reservoir, in combination with preventing, reducing, or minimizing the risk of degradation of reservoir properties in that area of the reservoir. For example, the mixing flow may be determined such that the mixed water or mixed injection fluid has a target salinity, TWTR, concentration of one or more cations, or a combination thereof, equal to a target value. For example, in embodiments, the mixing flow provides the target salinity in the mixed injection fluid. In the embodiments described below, the amount of HP is such that mixing at a mixing rate is used to dispose of the entire HP, in which the mixed injection fluid has a given salinity, TFR, concentration of one or more cations, or a combination thereof, exceeding the target value, but less than the threshold value, above which the PNR deteriorates. In embodiments where the amount of HP is such that disposal by existing disposal procedures (including the re-injection and non-re-injection disposal procedures described above) results in mixing at a mixing rate at which the mixed injection fluid has a salinity, TWF, concentration of one or more cations , or a combination of all of these parameters exceeds their threshold, instead of degrading the EOR in all of one or more EOR reservoir segments, one or more EOR reservoir segments can be reassigned for disposal, and the excess EOR is pumped back along the FAR route to one or more segments of the POR, reassigned as segment(s) for disposal. Thus, production from EOR can be continued in the remaining segments allocated for injection for EOR, and HP can be utilized in full through various disposal routes.

Method 1 also includes the dynamic distribution of the total amount of HP among various disposal procedures with re-injection (a) and without re-injection (b) (step 1E). The reverse injection procedure (a) includes reinjection into the reservoir through mixing with brackish or softened water and injection into one or more injection zones for EOR, injection into one or more disposal injection zones, or combinations of these procedures. The amount of HP injected back into the reservoir in (a) may thus be divided among one or more of: (c) the amount of HP mixed with the brackish or softened water stream to produce a brackish or softened water for the EOR having a total dissolved solids content (TSS) and ionic composition within the target salinity and target composition (e.g., within the target composition range) for EOR purposes and brackish or softened water for EOR injection into one or more reservoir segments, allocated for the secondary or tertiary regime of FOR with low-mineralized or softened water flooding; (d) the amount of HP used as a working and/or flushing fluid injected into one or more segments of the productive formation allocated for FST with brackish or softened water flooding after and/or before, respectively, injection of a plug of brackish or softened water therein for PNO; (e) the amount of HP used in the secondary production mode with injection into one or more segments

- 5 042218 tons of a productive formation, allocated for a tertiary FOR with injection of low-mineralized or softened water, before injection of a plug of low-mineralized or softened water there for FOR in the tertiary production mode; (e) the amount of HP injected as a waste stream into one or more reservoir segments designated for HP disposal; and (g) the amount of HP mixed with the brackish or softened water stream to produce a brackish or softened water stream for the ESP having a TSP and an ionic composition within the salinity and composition thresholds (e.g., within the composition range) for the purposes of the EOR, and injected as a plug of low-salinity or softened water for FOR into one or more segments of the productive formation allocated for the secondary or tertiary regime of FOR with low-salinity or softened water flooding; and/or (h) the amount of HP mixed with the brackish or softened water stream to produce a brackish or softened water for the EOR, having a salinity above the threshold salinity for the purposes of the EOR, and introduced into one or more segments of the reservoir. The amounts of HP allocated to each of procedures (c), (d), (e), (f), (g) and/or (h) may be maintained below injection limits for associated one or more reservoir segments.

Procedures for (b) disposal without re-injection include (i) offloading with produced oil, (j) overboard, or a combination of both. The quantity of HP present in the produced oil for shipment in procedure (i) may be kept below the maximum limit for shipment (e.g. for basic solids and water, T&W), and the quantity of HP discharged overboard in (k) may be maintained below maximum permitted overboard discharge limit. For example, an FTS&R limit may be less than about 3 volume percent (% vol.) of water or less than 5 volume percent (% vol.) of water, or an overboard discharge limit may be approximately 20,000 normal barrels per day (mstb/d) . A PW referred to as being part of a produced oil shipment to(s) may include or consist of a PW shipment through an injection into a PW/aquifer in a different rock. Discharge overboard in (k) comprises the discharge of water to the surface (eg, to the sea and/or rivers).

For a more detailed presentation of the various disposal procedures with or without re-injection (Step 1E), the following is a description of specific field equipment options with reference to FIG. 2 representing scheme I of a system or equipment for which the IP optimization tool described here can be used to distribute the utilization of IP. Scheme I of the equipment contains a device, or plant 30, for demineralization or softening of water, a line 35 for low-mineralized or softened water, a line 83 for produced water, suction manifolds, including a manifold 40 for low-mineralized or softened water and a recycling manifold 50, pressure pumps 60, pressure manifolds, including a brackish or softened water header 45 and a disposal header 55, a reservoir 65 containing one or more sections or segments dedicated to injecting during FOR flooding, and associated brackish or softened water injectors, one or more sections, segments or zones allocated for disposal and associated pumps of recycled water, and associated with one or more injection wells and one or more production wells, a separator 75 and an IW treatment device 80.

Device (installation) 30 demineralization or water softening allows you to get demineralized or softened water from the feed water in the line 21 of the feed water. Low-mineralized or softened water can be low-mineralized water obtained by reverse osmosis, nanofiltration, or a combination of them, or softened water obtained by nanofiltration (for example, in a water purification plant from sulfates, UOS), precipitation of hardness ions (for example, lime treatment), ion exchange , or a combination of them.

In embodiments, the demineralization or water softener 30 comprises reverse osmosis (RO) modules, nanofiltration (NF) modules, or a combination thereof. For example, in embodiments, the demineralization or softening device 30 comprises one or more RO/NF batteries, each of which contains several RO modules, each of the RO modules contains several RO membranes, and several NF modules, each of the NF modules contains several NF membranes. In some cases, reference may be made to UV filters, depending on the specific design, referred to as UV membranes. The RO flow can be diverted from the demineralization or water softener 30 through the RO line 32, and the NF stream can be diverted from the demineralization or water softener 30 through the NF line 33. One or more concentrate lines 29 can be used to remove concentrate from RO/NF batteries.

In another example, in the embodiment of FIG. 3 representing scheme II of the field equipment for which the IP optimization tool disclosed herein can be used to allocate the utilization of IP in accordance with another embodiment of the present disclosure, the demineralization or softening device 30 includes a demineralization system having three RO/NF batteries 30A, 30B and 30C, each of which is configured to produce from the feed water in the feed lines 21A, 21B and 21C, respectively, an RO stream or permeate in the RO lines.

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32A, 32B, and 32C, respectively, which are combined to form an RO permeate stream in RO line 32, and an NF or permeate stream in NF lines 33A, 33B, and 33C, respectively, which are combined to form an NF permeate stream in NF line 33. Each battery TOE/NF 30A, 30B and 30C may contain multiple TOE modules or groups thereof, NF modules or groups thereof, or combinations thereof. For example, in the embodiment of FIG. 3, TOE battery 30A contains TOE modules/groups 31A and NF modules/groups 31A', TOE battery 30B contains TOE 31B modules/groups and NF modules/groups 31B', and TOE battery 30C contains TOE 31C modules/groups and modules/groups. NF 31C. In embodiments, among other things, the RO modules can produce RO water with salinity or total dissolved solids (TSDS) less than or equal to about 300, 250, 200 ppm. In embodiments, among other things, the NF modules can produce NF water with a salinity or total dissolved solids content (TSDS) of less than or equal to about 30,000, 25,000, 20,000 ppm. If the amount of HP (for example, in line 70, described below) is high, the brackish or softened water device 30 can produce more water with RO permeate and less with NF permeate, thereby allowing mixing of RO water with more HP, as described below, while maintaining the salinity, or TSRTV, of the FOR composite stream within a target or threshold composition range.

In alternative embodiments, the demineralization or water softening device 30 includes a sulfate removal unit (SRP) to produce softened water. The FOS may contain several NF modules for the selective removal of multivalent ions to produce water with a reduced content of sulfates, as is known in the prior art.

In embodiments where the demineralization or water softener device 30 comprises a sulfate removal unit (SRP) or demineralization unit (as described above with reference to FIG. 3), an upstream filter, such as an ultrafiltration unit 20, may be used to removing large particles from the feed water 11, such as sea water (MB) obtained from the elevator 10 MB, to obtain a feed stream introduced into the demineralization or water softening device 30 through the water inlet line 21. In a membrane demineralization or water softening system, the feed water in the feed water inlet line 21 may contain sea water (MB), brackish water, aquifer water, or a combination thereof. UV device 20 may comprise any UV modules and membranes may be known to those skilled in the art. In embodiments, the UV or membrane modules are the same as those described in International Patent PCT/EP 2017/067443, published as WO/2018/015223, the disclosure of which is incorporated herein in its entirety for purposes not inconsistent with that disclosure.

In embodiments, the demineralization or water softening device 30 comprises a water softening device using ion exchange technology. This ion exchange technology is known in the art, for example, as described in International Patent Application PCT/US 2009/001816, published as WO/2009/123683, the disclosure of which is incorporated herein in its entirety for purposes not inconsistent with this disclosure. Although this disclosure is made in relation to ion exchange and regeneration of ion exchange resins with the resulting saturated solution, if present, in embodiments, sodium chloride (NaCl) or another salt of group IA of hydrohalic acid can be used to regenerate ion exchange resins.

In alternative embodiments, the demineralization or water softening device 30 comprises a device configured to produce softened water by removing hardness (eg, multivalent cations, eg, magnesium and calcium) from the feed water in the feed water line 21 through precipitation. For example, the demineralization or water softening device 30 can be used to produce softened water by liming the water, where the addition of lime (eg, calcium hydroxide) is used to remove hardness from the feed water through precipitation. The addition of lime (or other alkaline material) can be used to raise the pH so that the balance of carbon compounds in the water shifts to convert dissolved carbon dioxide to bicarbonate and further to carbonate, resulting in calcium carbonate precipitation. Magnesium hydroxide can also be precipitated, and liming the water can remove other polyvalent cations, such as iron, from the feed water.

In embodiments using ion exchange or hardness ion precipitation (e.g., water liming) to produce softened water for EOR purposes, formation water may be used as feed water (or at least a component thereof) in feed water line 21, thereby thereby forming other means of utilization of HP. This method may be advantageous over membrane demineralization or membrane softening (eg, UNS) in embodiments where minor amounts of oil in the IW typically poison such membranes. The possibility of obtaining softened water from HP can provide more flexibility in the disposal of HP.

The performance of the demineralization or softening water device, or installation 30, can be determined by the total consumption of HP utilization, the injection flow rate of low-mineralized or softened water (for example, injectivity requirements for low-mineralized or softened

- 7 042218 injection well water in one or more segments of the field for waterflooding with low-salinity or softened water during FST), and (for offshore installations) due to weight and size restrictions. As shown below, since all water injected is either formation water, or brackish water, or softened water for EOR, the difference between the injection rate of all water (determined by the requirements for replacing the reservoir voids) and the injection rate of the IW determines the relationship in the need for additional brackish or softened water (e.g. RO water). The maximum in this relationship can be used as a basis for determining the effective size of the demineralization or softening plant 30, taking into account contingencies or plug volume (for example, ± 10% contingency margin).

To dispose of excess brackish or softened water, a line 36 for dumping excess brackish or softened water can be used. In embodiments, discharge line 36 may be used to discharge excess RO water from RO line 32, and another discharge line 36 may be used to discharge excess NF water from NF line 33. In embodiments, excess RO/NF of water disposed of through the RO/NF discharge line 36 may be discharged into the sea. The amount of NF permeate stream 33 or RO permeate stream 32 available for mixing in forming the composite brackish or softened water injection stream(s) for FSP can be quickly adjusted (in real time) by diverting varying amounts of permeate NF stream 33 or stream 32 RO permeate from the demineralization unit 30, for example, into a body of water (eg, ocean) via a discharge line 36 of NF permeate or RO permeate or combined RO/NF permeate equipped with a relief valve. The unloader valve may be an adjustable valve (eg a throttle valve) that can be set to various positions (between fully closed and fully open positions) to control the amounts of NF permeate, RO permeate, or RO/NF permeate withdrawn from the system.

If the removal of excess NF permeate, excess RO permeate, or excess RO/NF permeate occurs for an extended period of time, for example, hours or days, then the control unit (for example, the control unit 90 discussed below) can make adjustments in the demineralization or softened water installation 30 by disabling one or more NF modules from the NF node or one or more RO modules from the RO node, thereby reducing the productivity of obtaining NF permeate or RO permeate, respectively.

At least a portion of the formation water in the IW line 83 may be mixed with the brackish or softened water in the brackish or softened water line 35 via the IW mixing line 84, by discharging the IW into the brackish or softened water header 85, or both. At least a portion of the brackish or softened water in the brackish or softened water line 35 may be introduced into the IW line 83 via the make-up line 37 with brackish or softened water. Thus, a portion of the brackish or softened water in line 35 may be mixed with the HP in line 83 via an HP mixing line 84 to produce a brackish or softened water and HP stream 35A, or a waste water stream 83A, a portion of the brackish or softened water in stream 35A may be introduced into the line 83 of the RW through the make-up line 37 of brackish or softened water, to obtain a stream 35B of brackish or softened water and a stream 83C of RW or recycled water, part of the RW in line 83 can be mixed through line 85 with a stream 35B of brackish or softened water, for supplying low-mineralized or softened water to stream 35C, and stream 83B of RW or waste water, or a combination of both. The brackish or softened water stream 35C may be introduced into the brackish or softened water suction manifold 40, and the RW or recycling stream 83C may be introduced into the recycling suction manifold 50. Although unlikely, in embodiments, feedwater in line 21 may be introduced into line 83 as needed to meet void replacement requirements, for example, seawater may be injected into reservoir 65 along with waste water containing HP.

The injection pumping device 60 comprises a plurality of pressure pumps used to pump brackish or softened water 35C introduced through line(s) 41 from the brackish or softened water suction manifold 40 into the brackish or softened water discharge manifold 45 through the line(s) 42 or into the injection manifold. recovery manifold 55 through line(s) 52, or pumping 83C recovery water introduced through line(s) 51 from recovery suction manifold 50 into low-salt or softened water discharge manifold 45 through line(s) 42 or into discharge manifold 55 recovery through-line (pits) 52. It is desirable that the pumping device contain enough pumps so that pumping from any manifold into any manifold is not limited by the available pumping capabilities. In the embodiment shown in FIG. 3, field equipment scheme II contains four injection pumps 60A, 60B, 60C and 60D. The pressure pump 60A is designed to pump water from the stream 35C supplied through line 41A from the brackish or softened water manifold 40 into the injection manifold 45 of brackish or softened water through line 42A, or into the

- 8 042218 disposal manifold 55 through line 52A, or for pumping waste water from stream 83C supplied through line 51A from the suction manifold 50 recycling into the low-salinity or softened water injection manifold 45 through line 42A or into the discharge manifold 55 recycling through line 52A ; pressure pump 60V is designed to pump water from the stream 35C introduced into it through line 41B from the brackish or softened water manifold 40, into the injection manifold 45 of brackish or softened water through line 42B or into the injection manifold 55 recycling through line 52B, or to pump recycling water from stream 83C introduced via line 51B from recovery suction manifold 50 to brackish or softened water discharge header 45 via line 42B, or to recovery header 55 via line 52B; the injection pump 60C is designed to pump water from the stream 35C introduced into it through line 41C from the brackish or softened water manifold 40, into the injection manifold 45 of brackish or softened water through line 42C or into the injection manifold 55 recycling through line 52C, or to pump recycled water from stream 83C introduced via line 51C from recovery suction manifold 50 to brackish or softened water discharge header 45 via line 42C or to recovery header 55 via line 52C; the pressure pump 60D is designed to pump water from the stream 35C introduced into it through line 41D from the low-salinity or softened water manifold 40, into the low-salinity or softened water injection manifold 45 through line 42D or into the disposal injection manifold 55 through line 52D, or to pump recycled water from stream 83C introduced via line 51D from recovery suction manifold 50 to brackish or softened water discharge header 45 via line 42D or to recovery header 55 via line 52D.

Water may be supplied from a brackish or softened water injection manifold 45 through line 46 and multiple brackish or softened water injectors into one or more reservoir segments 65, and from a recovery manifold 55 through line 56 and multiple recycling injectors into one or more reservoir segments 65 For example, as shown in the embodiment depicted in FIG. 3, brackish or softened water may be introduced through line 46 and the brackish or softened water injection manifold 45 and brackish or softened water injectors 47A, 47B, 47C and/or 47D, and line(s) 48 into one or more reservoir segments. 65, and utilizable water may be introduced via line 56 from disposal manifold 55 and injectors 57A, 57B, 57C, and/or 57D and line(s) 58 into one or more segments of reservoir 65. For example, reservoir 65 may contain any amount segments, such as segments 65A, 65B, 65C, 65D, 65E, 65F, 65G, 65H, 65I and 65J, according to the embodiment shown in FIG. 3. Low-mineralized or softened water may be introduced into one or more segments of the productive formation 65 allocated for EOR, while the utilized water can be introduced into one or more segments of the productive formation 65 allocated for disposal (or into one or more segments of the productive formation 65). of the formation allocated for FOR, when HP or recycled water is used as flushing and post-flushing water). Reservoir 65 may contain any number of segments dedicated to EOR and any number of segments dedicated to disposal, and their distribution can be changed in accordance with the dynamic optimization of the ST described here.

Preferably, one or more utilization areas or segments of the reservoir 65 are separated from one or more segments of the brackish water flood, since it is undesirable for the IW to pass from the utilization segment to the segment of the brackish water flood and negatively affect the efficiency of the EOR. For example, one or more sections or segments may be physically separated by various geological formations (eg, impermeable boundaries or layers) and/or spatially separated to create resistance to flow from one segment to another. One or more segments 65A-65I of reservoir 65 may be used for secondary EOR with brackish or softened water flooding, one or more segments 65A-65I of reservoir 65 may be used for tertiary EOR with waterflood after secondary IW, or a combination thereof . Reservoir segments can be prioritized to inject brackish or softened water in secondary production, inject brackish or softened water in tertiary production (for example, after injection of PW), or for disposal of PW, depending on the amount of oil available in each segment , and the response to brackish or softened water flooding in each segment, such as how well reservoir rock responds to brackish or softened water flooding in core water experiments. Segments may be initially allocated to secondary EOR, tertiary EOR, or disposal, with the overall goal of recovering the maximum amount of additional oil in EOR with brackish or softened water flooding under operating conditions within system constraints, including disposal of the entire IW. As shown in patent application GB 1714649.9, the disclosure of which is incorporated herein in its entirety for purposes not inconsistent with this disclosure.

- 9 042218 tiyu, the salinity of brackish or softened injection water for EOR can be controlled in the process of flooding brackish water oil-bearing reservoir, when the formation rock surrounding the first injection well has a chemical characteristics that differ from the chemical characteristics of the formation rock surrounding the second injection well, which leads to a different risk of deterioration of the reservoir properties of the reservoir (for example, loss of permeability), due to the injection of low-salinity or softened IOR injection water from the injection well into the reservoir. In such embodiments, it is possible to control the concentration of one or more individual ions, or by type of individual ions, in the low-salinity or softened EOR injection water(s) pumped into injection wells 47 drilled in different segments or sections of the reservoir 65 having different rock characteristics, causing various risks of deterioration of the reservoir properties of the formation.

Because the salinity and TWTR can be relatively higher at the start of the operation (because the salinity of the surviving formation waters can be relatively high), and decrease over time as brackish or softened water infiltrates production wells in field segments where secondary flooding occurs brackish or softened water or tertiary brackish or softened water flooding, the amount of HP that can be recovered by mixing with brackish or softened water can increase over time, and the dynamic distribution of HP disclosed in the present invention allows efficient utilization of varying amounts of HP.

Production from the field, including oil, formation water, and/or gas produced from reservoir 65 through one or more production wells, may flow through line 72 to separator 75. Separator 75 may be a high pressure/low pressure (HP/LP) separator. , providing separation of marketable oil, which can be sent through line 77 for shipment, from formation water, which can be sent through line 76 to the block, or device, 80 for processing PV. Processed PV can be diverted from the block, or device, 80 processing PV through the line 81 processed PV. For example, as shown in the embodiment of FIG. 3, a product containing oil, HP and gas is introduced through line 70 and production wells 71A, 71B, 71C and 71D into HP/LP separator 75. Separator 75 separates the commercial oil in line 77 from most of the RO that is withdrawn from separator 75 via line 76. The OP in line 76 may be treated by passing through an RO treatment device 80, for example, to recover oil therefrom. In embodiments, discharging HP overboard includes treating the HP to dump it overboard to extract oil from it. The IW treatment device 80 may be a standard water treatment module adapted to remove oil from the IW to meet environmental requirements for waste water. These rates may vary by region, for example, less than 40 ppm of oil in water.

As will be shown below, the distribution of HP may include overboarding a portion of the HP in the HP treatment line 81 via the overboard line 82, and the remainder of the HP in line 83 may be pumped back into the reservoir 65 through brackish or softened water (for example, through mixing with brackish or softened water in line 35 through line 84 of mixing HP, discharge of HP into line 85 of a collector of brackish or softened water, or both) or as waste water.

Returning to FIG. 1, note that the dynamic distribution of the production rate of IW between the re-injection procedure and the non-reinjection procedure in step 1E may include (a) re-injection into the reservoir 65 by mixing with low-salinity or softened water in line 35 through lines 84 and/or 85 , and injection into one or more segments of the reservoir 65 allocated for disposal; (b) disposal by one or more disposal procedures without re-injection, or a combination thereof. When a portion of the brackish or softened water is produced from HP, the amount of HP recovered through the production of brackish or softened water from it is intended to be included in this case in (a) reinjection into the reservoir 65 by mixing with the brackish or softened water in line 35 through the lines 84 and/or 85 and injecting into one or more segments of the productive formation allocated for EOR, or reinjecting the utilized water into one or more segments of the productive formation 65 allocated for disposal.

In embodiments, disposal by one or more of the non-reinjection procedures in (b) comprises shipping (i) via line 77 of produced oil, (k) overboard via line 82, or a combination thereof. The amount of HP disposed of through shipment(s) as part of produced oil via line 77 and/or discharge to (to) overboard via line 82 can be maintained below thresholds. As noted, non-reinjection disposal procedures may also include disposal into a shallow aquifer or formation via a disposal well. Discharge overboard may be undesirable for environmental reasons and may be kept below the maximum allowable discharge.

The amount of HP injected back into the reservoir in procedure (a) can be divided

- 10 042218 among one or more of: (c) an amount of HP mixed with a brackish or softened water stream to obtain a brackish or softened water flow for FSP, having a mineralization less than the target mineralization value for FSP and introduced as a plug of brackish or softened water for FOR in one or more segments of the productive formation allocated for secondary or tertiary FOR with low-salinity or softened water flooding; (d) the amount of HP used as a working and/or flushing fluid injected into one or more segments of the productive formation allocated for flooding with brackish or softened water for EOR, following and/or before, respectively, injection of a plug of brackish or softened water therein water for PNO; (e) the amount of IW used in the secondary production mode by injecting into one or more reservoir segments allocated for tertiary brackish or softened water flooding for FOR prior to injecting the brackish or softened water plug into them for FOR in the tertiary production mode; (e) the amount of HP injected by the disposal stream into one or more segments of the reservoir for disposal of the HP; and/or (g) the amount of HP mixed with the brackish or softened water stream to produce a brackish or softened water flow for FSP, the salinity of which is less than the threshold salinity for FSP purposes, and introducing in the form of a plug of low-mineralized or softened water for FSP into one or more reservoir segments allocated for secondary or tertiary FOR using brackish or softened water flooding; and (h) the amount of HP mixed with the brackish or softened water stream to produce a brackish or softened water for the FOR, the salinity of which exceeds the threshold salinity for the FOR, and injected into one or more segments of the reservoir; while the amounts of HP allocated for each of the procedures (c), (d), (e), (f), (g) and/or (h) are maintained below the injection limits for the associated one or more reservoir segments.

Dynamic distribution maintains injection flow at FOR, injection flow in the disposal zone, and disposal flow without re-injection below the specified limits, providing disposal with or without re-injection of the total production rate of IW, and corresponds to the total replacement flow of voids, at which the total amount of water pumped back into (a) is equal to the void filling requirement.

Thus, the production rate of IW in line 72 is distributed between the flow rate of offloaded oil in line 77, the flow rate of discharge overboard through line 82 of the discharge overboard, and the rate of re-injection of IW (RWR) into the reservoir 65. The flow rate of WWR in line 83 is divided between the flow rate of mixing with brackish or softened water in the mixing line 84, the flow rate of combining with brackish or softened water in the discharge line 85 and/or the flow rate of re-injection into the productive formation 65 IW in the form of reclaimed water in 83B.

The dynamic distribution in step 1E can prioritize the distribution of formation water first for (and) shipment in produced oil, when the maximum possible amount of IW is diverted with commercial oil. The dynamic distribution in step 1E may prioritize the distribution of formation water last in (h), whereby mixing some of the HP with the brackish or softened water flow to obtain a brackish or softened water flow for the FOR having a salinity above the salinity threshold before the FOR, and injected into one or more reservoir segments is used only when all other HP utilization procedures are not sufficient to distribute the total HP in line 72. the maximum possible discharge overboard within the established limits is used for the disposal of HP only after the maximum use of the possibilities of all other disposal procedures, except for mixing HP in (h). Thus, overboard discharge in (k) can be used only if it is necessary to prevent the discharge of HP into the collector of brackish or softened water, which would lead to a flow of brackish or softened water for FOR with salinity above the threshold salinity for FOR, which, possibly, will lead to losses during the PNO.

In embodiments, the EOR is conducted by injecting a brackish or softened water plug rather than continuously pumping it. For example, in embodiments, the brackish or softened water plug for FSP has a pore volume less than or equal to about 0.9, 0.8, 0.7, 0.6, 0.5, 0.4, or 0.3. The measurement data obtained in 1A may include the composition range for the PNR. The low-salinity or softened water stream for POR may have a composition as described, for example, in International Patent Application PCT/GB 2007/003337 published as WO/2008/029124 or International Patent Application PCT/US 2009/001816 published as WO /2009/123683, the disclosure of which is incorporated herein in its entirety for purposes not inconsistent with these disclosures. For example, a brackish or softened water stream for ESP (e.g., a mixed stream of RW and brackish or softened water, or initially, a DS/NF stream) may have a total dissolved solids content (TSDS) of in

- 11 042218 interval from 200 to 10000 ppm, and the part of the total content of polyvalent cations relative to the total content of multivalent cations in the relict water of the reservoir 65 may be less than 1, or both. The system may have sensors, such as sensors S1, S2, S3, S4, S5, S6, S7, shown in the embodiment of FIG. 3, configured to measure the concentration of ions, for example, salinity, total concentration of dissolved ions, or concentrations of individual ions (Ci), flow rates, or a combination of these parameters in different streams, for example, nanofiltration permeate (S1), RO permeate (S2), an RO/NF flow (S3), a brackish or softened water mixture stream 35B (S4), a brackish or softened water mixture stream 35C introduced into the brackish or softened water collector 40 (S5), a treated RW stream (S6), or a waste water stream to be introduced into the disposal manifold 55 (S7). Ion concentration sensors, flow sensors, and any other sensors described herein can communicate with a control unit (e.g. control unit 90) using any means of communication, e.g. direct electrical connection or wireless electrical connection (e.g. Wi-Fi, Bluetooth) . Other sensors and their uses are also covered by this disclosure.

As described in UK Patent Application GB 1714649.9, various sensors (probes) can be included in the RO optimization system of the present invention, in particular in a mixing system. These sensors can be used to determine the TRTW and/or the ionic composition of the brackish or softened water component stream(s), such as streams 35A, 35B and/or 35C. For example, the TPRT of the composite stream(s) of brackish or softened water can be determined by its conductivity, while the concentration of individual ions or individual ions by ion type can be determined using glass probes having membranes that are permeable to specific individual ions or individual ions by ion types. Similarly, probes (sensors) may be installed on one or more RO permeate lines 32/32A/32B/32C, one or more NF permeate lines 33/33A/33B/33C, any combined RO/NF permeate lines 35, or combinations thereof. , to obtain data related to the TRTW and ionic composition of the RO permeate stream(s), the NF permeate stream(s), any combined 35 RO/NF permeate stream(s), or a combination thereof. Flow sensors may also be installed in the flow lines to determine the flow rates of the various mixed streams of the RO permeate stream(s), the NF permeate stream(s), any combined RO/NF permeate stream(s), the IW mixing line 84, the IW discharge line 85, and etc.) and to determine the flow rates of RO permeate in the RO discharge line and NF permeate in the NF discharge line, or discharge line 36 of the combined RO/NF stream.

The target salinity for an EOR plug (comprising a composite stream of 35C brackish or softened water and HP, or (initially) a 35 RO/NF stream) is the predicted mineralization for obtaining the best EOR. In embodiments, the target salinity, or TSRTV, for the brackish or softened water used for FSP is less than or equal to about 3000, 2000, or 1500 ppm. The threshold salinity or TSR is the salinity or TSR that is higher than the target salinity or TSR but has the maximum values at which the enhanced oil recovery effect (ER) due to brackish or softened water flooding is still maintained. In embodiments, the threshold mineralization or TSR is less than or equal to about 10,000, 9,000, or 8,000 ppm. In embodiments, the RO water in line 32 has a salinity or TRTW of less than or equal to about 300, 250, or 200 ppm, and the HP (and/or NF permeate) is mixed with the RO water through mixing line 84 (and/or NF line 33) to to obtain mixed water having a target salinity or TWR and is pumped back into the reservoir 65 in the form of a plug of brackish or softened water for EOR, and the remaining WWW in the line 83 for re-injection is disposed of by injection into one or more segments of the reservoir 65 allocated for recycling. In embodiments, the NF permeate in line 33 has a salinity or TFR in the range of about 40,000 to 60,000, about 45,000 to 55,000, or about 47,500 to 52,500, or about 40,000, 45,000, or 50,000 ppm. When commissioning an injector well, salinity can be controlled as described in GB 1712847.1, titled Method for Controlling Salinity in Commissioning a Low Salinity Fluid Injection Well, the disclosure of which is hereby incorporated in its entirety for purposes not inconsistent with these disclosures.

In embodiments, the dynamic distribution in step 1E further includes a condition such that if the total amount of HP to be distributed is such that the amount of HP in procedure (h) [e.g., the amount of HP mixed with a brackish or softened water stream to obtain a brackish or softened water stream of softened water for FOR, having a salinity above the threshold salinity for FOR, and injected into one or more segments of the reservoir] will not be equal to zero, one or more segments of the reservoir 65, allocated for injection of low-salinity or softened water for FOR, are converted into segments for allocation for disposal so that the amount of HP in (e) [for example, the amount of HP injected through the recycling stream into one or more segments of the reservoir allocated for disposal of HP] can be increased, and the amount of HP in (h) remains equal to zero, thanks to which the rest of one

- 12 042218 or more reservoir segments allocated for low-salinity or softened water for FSP, low-salinity or softened water for FSP, having a salinity below the target or threshold salinity for low-mineralized or softened water for FSP, can still be directed through (c) [ e.g., the amount of HP mixed with a brackish or softened water stream to produce a brackish or softened water for FSP stream having a TSP and an ionic composition within the target composition range for the FSP, and introduced as a plug of brackish or softened water for the FSP into one or more reservoir segments allocated to a secondary or tertiary EOR with brackish or softened water flooding], or (g) [e.g., the amount of IW mixed with a brackish or softened water stream to produce a brackish or softened water stream for an EOR having a TSPW and an ionic composition before the threshold composition range for FOR, and introduced as a plug of brackish or softened water for FOR in one or more segments of the productive formation, allocated for secondary or tertiary FOR with brackish or softened water flooding]. Thus, the reassignment of one or more segments of the productive formation 65 from use for EOR to disposal allows the use for disposal of excess HP in the newly allocated segment (s) for disposal, while maintaining the salinity level of the brackish or softened water stream for EOR suitable for EOR (for example, at a salinity level less than or equal to the target salinity, or at least less than or equal to the threshold salinity above which the PSP becomes ineffective). The dynamic allocation of IW disposal procedures and the corresponding designation of the reservoir segment(s) 65 as a salvage segment or IOR, in accordance with the present disclosure, can thus ensure complete IW utilization while maintaining the maximum possible IOR.

In embodiments, the amount of HP injected back into the reservoir comprises (c) (the amount of HP mixed with the brackish or softened water stream to produce a brackish or softened water flow for the FOR, the salinity of which is less than the target salinity for the FOR injected as a brackish plug or softened water for EOR in one or more reservoir segments allocated for secondary or tertiary EOR with brackish or softened water flooding), (f) (amount of HP pumped through the disposal stream into one or more reservoir segments allocated for the disposal of HP ), (g) (the amount of HP mixed with a low-mineralized or softened water flow to obtain a flow of low-mineralized or softened water for FSP, with a salinity less than the threshold mineralization for FSP purposes, and introduced as a plug of low-mineralized or softened water for FSP into one or more product segments of an active formation allocated for a secondary or tertiary EOR with brackish or softened water flooding) and (h) (amount of HP mixed with a brackish or softened water flow to obtain a brackish or softened water flow for FOR, the salinity of which exceeds the threshold salinity for the purposes of FOR, and introduced into one or more segments of the reservoir), and the distribution of water prioritizes in the order of (i) (amount of HP withdrawn in the shipped oil), (c), (e), (g), (j) (amount of HP, thrown overboard), (h).

In embodiments, the amount of HP re-injected through procedure (c) (e.g., the amount of HP mixed with the brackish or softened water stream to produce a brackish or softened water stream for the FSP having a total dissolved solids content (TSDS) and an ionic composition of within the target composition range for FOR, and injected as a plug of brackish or softened FOR water into one or more reservoir segments isolated for secondary or tertiary FOR with brackish or softened water flooding), (d) (e.g., amount of HP used as a working and / or flushing fluid injected into one or more segments of the productive formation allocated for FOR with brackish or softened water flooding after and / or before, respectively, injection of a plug of brackish or softened water for FOR), (e) ( for example, the amount of HP used in secondary production mode by injecting one or more reservoir segments designated for tertiary EOR with brackish or softened water flooding before injecting a brackish or softened water plug for FOR in the tertiary production mode), (g) (e.g., amount of HP mixed with low-mineralized or softened water flow to obtain a low-mineralized or softened water flow for EOR, having a TWPW and an ionic composition within the threshold range of the composition for EOR, and introduced in the form of a plug of brackish or softened water for EOR into one or more segments of the productive formation, allocated for the secondary or tertiary FSP with brackish or softened water flooding); and (h) (e.g., the amount of HP mixed with a brackish or softened water stream to produce a brackish or softened water flow for the FOR, the salinity of which exceeds the threshold salinity for the FOR purposes, and injected into one or more segments of the reservoir), injected into the associated one or

- 13 042218 more segments of the productive formation 65 through the low-salinity or softened water for EOR manifold 40, several injection pumps 60 and the low-salinity or softened water for EOR manifold 45, and the amount of HP re-injected by (e) for disposal is injected into one or more segments reservoir 65 allocated for disposal through a disposal manifold 50, several injection pumps 60 and a disposal manifold 55. A plurality of pressure pumps 60 may be in fluid communication with the brackish or softened water EOR manifold 40 and the disposal manifold 50, and be in fluid communication with the brackish or softened water manifold 45 and the recycling manifold 55.

The dynamic allocation in step 1E may also take into account the number of reservoir 65 segments available for disposal, the number of reservoir 65 segments available for low salinity or softened water at FOR, injection parameters requirements, including target and threshold salinities, flow rates and pore volumes for brackish or softened water for EOR pumped into segments of EOR with brackish or softened water flooding, the capacity of the injection pumps for the disposal manifold is 50, the capacity of the injection pumps for the manifold is 40 brackish or softened water for the EOR, the capacity of the reservoir is 45 brackish or softened water, the reservoir capacity is 55 recycling or a combination thereof.

In embodiments, the dynamic allocation in step 1E also takes into account that if the distribution in order of priority (i), (c), (f), (g), (j), (h) will exceed the capacity of the pumps for the manifold 40 low-mineralized or softened water, the injection of low-mineralized or softened water from it will be reduced if, when distributing in order of priority (i), (c), (f), (g), (k), (h), the pump capacity for the manifold is exceeded 50 disposal, the injection of reclaimed water from it will be reduced, or these reductions will be combined.

In the embodiments, the dynamic distribution in step 1E also takes into account that if the distribution in order of priority (i), (c), (e), (g), (j), (h) will exceed the capacity of the reservoir 45 of brackish or of softened water for EOR without exceeding the productivity of the first subgroup of injection pumps 60 that inject water into it, one or more segments of the productive formation 65 are switched to a collector 45 of low-mineralized or softened water for EOR, while one or more segments are switched from use for disposal to distribution for low-mineralized or softened water for PNO, to provide additional injection performance; if, in the distribution in order of priority (i), (c), (e), (g), (j), (h), the capacity of the disposal collector 55 is exceeded without exceeding the capacity of the remaining pressure pumps 60 pumping water into it, one or more segments of reservoir 65 are switched to disposal header 55 from brackish or softened water for EOR header 45, with one or more segments switched from use for brackish or softened water for EOR to distribution for disposal, to provide additional injection capacity, or these reallocations will be combined.

Also disclosed is a system for the dynamic distribution of formation water (PW) for disposal in a productive formation in the process of waterflooding with brackish water. (Although this system is described below in relation to brackish water flooding and brackish water, it can also be applied to soft water flooding and soft water). The system is shown in Fig. 4, which is a block diagram of a system III for dynamically distributing HP for disposal in a reservoir during a brackish water flood. System III includes: a storage device 93, a storage means 92 of dynamic allocation (DDR); and a processor 91 in communication with the memory 93. The dynamic allocation means 92, when executed by the processor 91, configures the processor 91 to: receive reservoir data containing a determination of the distribution of one or more reservoir segments as disposal segments and one or more reservoir segments as segments for waterflooding for EOR, and the total production cost of IW (step 94); entering into the dynamic distribution engine 92 data containing the distribution of one or more reservoir segments and the total production costs of the IW (step 95); preliminary (qualitative) assessment of the enhanced oil recovery (EOR) structure with brackish water flooding by segments for each of one or more segments and the total enhanced oil recovery (step 96); numerical evaluation of various procedures and costs of disposal of HP with and without reverse injection (step 97); and determining, based on the preliminary estimate in step 96 and the numerical estimate in step 97, one or more disposal routes for the PV (step 98). As shown above with reference to FIG. 1-3, one or more disposal routes may comprise: one or more re-injection routes selected from (a) mixing with a brackish stream produced in a brackish facility to produce brackish water for the EOR, for injection into one or more segments of the EOR with brackish water flooding; (b) reinjection as disposal water into one or more of the disposal segments; or

- 14 042218 a combination of these routes, and/or one or more disposal routes without re-injection, containing (c) shipping in produced oil; (d) discharge, or a combination of these routes, in which the cost of disposal of HP through (a), (c), (c), (d) or their combination is equal to the total cost of withdrawal of HP.

As shown above with reference to FIG. 2 and 3, in the embodiments, the data obtained in step 94 and/or entered in step 95 may also include the brackish or softened water flow capacity of the brackish water device 30, the number of injection pumps 60 available to inject brackish water for POR from manifold 40 brackish water for ESP or recycled water from recovery manifold 50 to header 45 brackish water for ESP, number of injection pumps 60 available to inject brackish water for ESP from manifold 40 brackish water for ESP or waste water from manifold 50 disposal to manifold 55 disposal, the maximum capacity of each pump 60, the minimum allowable flow rate of each pump 60, the target salinity or TRR (for example, the target composition range) when injecting low-salinity water for EOR, the maximum allowable or threshold salinity or TLR for low-min slurry water for FOR (e.g. composition threshold range), lag of formation water parameters due to FOR with brackish water flooding (e.g. predicted lag in production of IW at FOR) brackish water plug size for FOR as a fraction of pore volume (PV) for each of the segments for the FST with low-salinity waterflooding, the FST of each segment, the start date of injection of the FST or low-salinity water for the FST for each segment with the FST, or a combination of these data. The processor 91 may also provide output data, such as through a display 99, showing the operation of the brackish or softened water preparation device 30, the discharge header and salinity rates for each brackish or softened water discharge header 45 and the recovery header 55, the mode of operation of each pressure pump 60, and brackish water preparation device 30 (eg, RO battery operating mode), injection rates by segment, or a combination of these data.

Processor 91 may be used to identify (and provide appropriate data) the pump usage patterns for various re-injection procedures, quantified. The processor may have three pump usage modes, including a first or good mode, indicating that each of the pressure pumps 60 is for one of the low-salinity water EOR manifold 45 or the disposal manifold 55; a second mode, or acceptable mode, indicating that the injection pump 60 is designed to inject brackish water for EOR from the brackish water manifold 40 into both the brackish water for EOR manifold 45 and the disposal manifold 55; and a third mode, or unacceptable mode, showing that the pressure pump 60 is designed to inject brackish water for EOR from the brackish water manifold 40 into the brackish water for EOR water collector 45 and recycled water from the recycling manifold 50 into the recycling manifold 55. If any third or unacceptable modes are determined, the processor 91 and/or the user may reconsider the cost and disposal procedures for the HP at step 97 and/or determine other disposal routes for the HP at step 98 by increasing or decreasing injection into one or more segments to obtain the first or a second mode for each of the injection pumps 60.

In embodiments, if processor 91 determines in step 98 that excess brackish water for EOR has been directed to disposal manifold 55 (eg, through brackish or softened water make-up line 37), one or more additional segments of reservoir 65 may be isolated (for example, , from the disposal segment(s)) as segments for BSA with brackish water injection, since such excess brackish water for BSP has become available, and data on such reallocation is entered into the dynamic allocation engine (DDR) 92 at step 95.

RDD 92 may also require processor 91 to fulfill the following conditions, in addition to meeting the condition that the sum of the costs of disposing of the HP in procedures (a), (b), (c), and (d) is equal to the total flow rate of withdrawal of the HP: the total flow rate of water injection into one or more EOR segments in (a) and one or more disposal segments in (b) are greater than or equal to the estimated IW re-injection rate equal to the predicted total IW withdrawal rate minus the IW disposal costs through (c) and (d); a low-salinity stream for EOR (for example, a 35C stream) has a total salinity equal to the target salinity; the salinity in the reservoir 45 of low-mineralized water for PNO is less than the threshold mineralization for the purposes of PNO; the brackish water preparation device 30 has a brackish flow capacity sufficient to produce a brackish water stream; the number of required injection pumps 60 does not exceed the total number of available injection pumps 60; each of the injection pumps 60 is used in the injection mode in excess of the minimum allowable flow; discharges and mineralizations are greater than or equal to zero, or a combination of these conditions occurs.

The processor 91 can be configured to distribute the brackish flow (for example, in the brackish water line 35) and the SW (for example, in the BW line 83) between the brackish water for EOR and the disposal manifold 55, with the SW being pumped back through procedures (a) or (b), is first sent to the recovery manifold 55 for disposal according to (b), and the brackish water produced in the brackish water device 30 is preferably sent to the brackish water collector for mixing with the brackish stream for PNO as in (a).

In embodiments, the brackish water preparation device 30 comprises one or more reverse osmosis (RO) modules 31 (e.g., RO modules or groups 31A/31B/31C of the embodiment in FIG. 3), and processor 91 can be further configured to account for performance RO module 31 to produce RO water, and the number of modules 31 available. RDD 92 may instruct processor 91 to preferentially distribute RO water to line(s) 32 for disposal by mixing with HP, as in (a), mixing with nanofiltration water ( NF) in the absence of PV, for example, in the initial stages of PNO, or both.

In embodiments, system III may be used to develop field equipment, such as equipment I shown in FIG. 2 or equipment II shown in FIG. 3, for a low-salinity waterflood (for example, the capacity of the low-salt or softened water preparation device 30, the size and number of pumps 60, etc.), or to analyze and / or redistribute segments of the reservoir 65, procedures for the disposal of IW, or both another within the existing equipment for EOR with low-salinity waterflooding. In the embodiments, the processor 91 in step 94 calculates or receives the measured salinity of the low-salinity water for the FSP, for the injection according to (a) and the salinity of the utilized water, and one or more segments allocated for the injection of the low-salinity water for the FSP are reallocated for disposal if the numerical evaluation in step 97 indicates that the mixed water in (a) has a salinity above the target salinity, or above the threshold salinity for use in the FSP.

As described with reference to the same FIGS. 2 and 3, also disclosed is a system for simultaneously injecting brackish water and formation water for disposal into a reservoir 65 containing multiple segments (e.g., segments 65A-65I in the embodiment of FIG. 3), including: a brackish water treatment system 30 configured with the possibility of generating a flow of low-mineralized water; a separation system 75 configured to separate commercial oil shipped via oil export line 77 from a production well product (eg, in line 72) containing oil, HP and gas, while diverting HP to line 76 for disposal; a brackish water injection manifold 40 having fluid connection via a brackish water line 35 to a brackish water preparation system 30; a disposal manifold 50 having a fluid connection via a disposal line 83 to a separation system 75; one or more injection pumps 60 in fluid communication with the brackish water injection manifold 40 and the disposal injection manifold 50; a brackish water injection manifold 45 in fluid communication with one or more injection pumps 60, whereby a brackish water stream for the EOR, containing at least a portion of the brackish water stream, can be injected into one or more segments of the productive formation 65 allocated for FOR with low-salinity waterflooding; a disposal injection manifold 55 in fluid communication with one or more injection pumps 60 whereby a disposal stream containing at least a portion of the disposal HP can be pumped into one or more disposal segments 65; a mixing line 84 providing a fluid connection of the disposal line 83 to the brackish water line 35, whereby a portion of the waste water to be disposed of can be mixed with the brackish water stream to produce a brackish stream for the EOR before being introduced into the brackish water manifold 40; and a control unit or system 90 containing a processor 91.

The control unit 90 may include a CPU (central processing unit) 91, a storage device 93 (for example, RAM (Random Access Memory), ROM (Read Only Memory)), a hard disk, input/output interfaces, a display 99, etc., and may be implemented by executing in the CPU 91 a program including a dynamic allocation means (DMA) and stored in a storage device (eg, RAM). The RDD 92 may configure the processor 91 (when executed by the processor) to perform any of the steps and methods described herein. At the same time, the processor 91 contains software tools that allow it to: determine the injection rates per segment that meet the requirements for filling pores and injection for FOR, ensuring the dynamic allocation of all HP for disposal through one or more routes of re-injection, one or more routes without re-injection or combinations thereof, with one or more re-injection routes being selected from injection into injection manifold 55 through disposal line 83, injection into injection manifold 45 through brackish water through line 84, or a combination thereof. As shown by dotted lines in FIG. 2, the control unit 90 may be used to control (via valves not shown in FIG. 2) the flow in one or more of

- 16 042218 lines 32 (RO permeate lines), lines 33 (NF permeate lines), lines 97 (SW shipment together with oil), (SW discharge overboard), 84 (SW mixing with brackish or softened water to achieve the target or, at least the threshold salinity), 35 (TOS/NF water), discharge line(s) 36, 37 (volumes of low-mineralized make-up water to the disposal line), 85 (discharge of HP into the low-mineralized or softened water collector with salinity above the threshold).

Typically, cut-off values (or composition ranges) for the TWTS of the brackish water injection stream(s) for FSP can be in the range of 200 to 10,000 mg/L, preferably 500 to 10,000 mg/L. In general, lower TRT intervals provide higher EORs, while higher TRT intervals reduce the risk of deterioration of reservoir properties, especially in fields containing rocks with a high proportion of swellable and/or migrating clays. Other cut-off values for TPTS can be, for example, values in the range 500 to 5000 mg/l, 500 to 3000 mg/l, 1000 to 2000 mg/l, 2000 to 5000 mg/l or 3000 to 7000 mg/l (depending on the risk of deterioration of the reservoir properties of the formation). This or another control unit 90 may control the compositions of brackish or softened waters for segments with EOR of the productive formation, in order to keep them within the specified limits of the boundary values of the TSR.

In the event that there is a risk of acidification or scaling in the reservoir 65, the control unit 90 may adjust the concentration of sulfate anion in the mixed low-salinity or softened injection water for EOR for the reservoir segments to a value of less than 100, 50 or 40 mg/l.

The control unit 90 can be used to control the total concentration of multivalent cations of mixed low-salinity or softened injection waters for EOR for segments of EOR of the productive formation so that it is, for example, in the range from 1 to 250 mg/l, from 3 to 150 mg/l , or from 50 to 150 mg / l, with the condition that the ratio of the content of multivalent cations in mixed low-mineralized injection water (s) to the content of multivalent cations in the relict water contained in the pore space of the reservoir rock, for each segment or area of the reservoir 65 , is less than 1. The control unit can be used to control the calcium cation concentration of mixed injection waters for EOR for injection into segments for EOR of the productive formation 65 so that it is in the range from 1 to 200 mg / l, 5-150 mg / l, or 50-150 mg / l, with the condition that the ratio of the calcium cation content of the mixed low-mineralized supercharger ion water(s) to the calcium cation content of relict water located in the pore space of the reservoir rock of each segment or area of the reservoir 65 is less than 1.

The control unit 90 may be used to control the magnesium cation concentration of the mixed FOR injection waters for the reservoir FOR segments 65 to be in the range of 2 to 400 mg/L, 10 to 300 mg/L, or 100 to 300 mg. /l, provided that the ratio of the magnesium cation content of mixed low-salinity injection water(s) for FOR to the content of magnesium cation in the relict water contained in the pore space of each segment or area of the productive formation 65 is less than 1.

The control unit 90 can be used to control the potassium cation concentration of the mixed injection waters for the EOR for the reservoir segments 65 so that it is in the range from 10 to 2000 mg/l, in particular, from 250 to 1000 mg/l, with the condition, that the TWR of the mixed low-salinity injection water(s) for the FSP remains within the boundary values of the specified operating range.

The control unit 90 can be used to control the composition of the mixed low-salinity injection water for the EOR, maintaining it within a predetermined range defined by the boundary values for the TSPTV (and within predetermined intervals defined by the boundary values for the content of multivalent cations, the content of the calcium cation, the content of the magnesium cation and / or potassium cation content) for the TWRT limit overlap region (and for the polyvalent cation content, calcium cation content, magnesium cation content, and potassium cation content overlap region) for one or more segments and regions of reservoir 65.

Boundary values for TSP and individual ion concentrations and the concentration of any brackish injection water shale stabilizing additive for EOR may vary depending on the response of the EOR in the brackish water flood for each reservoir segment 65 and the rock composition of the oil-bearing layer(s) of each reservoir segment 65 and, in particular, levels of swellable and migrating clays and minerals known to be associated with degradation of reservoir properties.

The control unit of the demineralization or water softener plant 30 can change the operation of the demineralization or water softener plant 30 in real time to match the amounts of RO permeate, NF permeate, and admixture of HP streams to be mixed, thereby maintaining the composition(s) of the low-salinity or softened water composite streams for PNO within the specified operating range(s) that have been entered into the control unit. The control unit 90 can automatically adjust the mixing and hence the amount of RO permeate flow (e.g., in line(s) 32), NF permeate (e.g., in line(s) 33), mixing RH flow in line 84 (and any optional MB stream or clay stabilizer concentrate), or combinations thereof, that are included in the composite brackish or softened water stream(s) for FOR (e.g., to form a 35C brackish or softened water for FOR) in response to well injectivity changes in one or more productive formation segments 65.

The compositional range limits for the FOR of the segment(s) can be determined by analyzing reservoir rock samples taken from each area of the reservoir 65 oil layer. Alternatively, analysis of the reservoir rock surrounding the injection wellbore may be performed by geophysical logging using downhole logging equipment. Rock analysis for each region of the reservoir 65 may include, among other things, determining the total mudstone content in the reservoir surrounding the injection wellbore(s) in different segments or regions of the reservoir. The total content of mudstone in the reservoir rock for segments or regions of the reservoir can be determined by geophysical logging, X-ray diffraction (XRD), scanning electron microscopy (SEM), scintillation counter in the IR range or sieve analysis. The total content of mudstone in the formation rock can be in the range from about 2 wt.% to about 20 wt.%. The analysis of the rock for each area of the oil-bearing layer of the reservoir may also include determining the mineral content in the clay fraction of the rock, in particular smectic type clays (for example, montmorillonite clay), pyrophyllite type, kaolinite type, illite type, chlorite type and glauconite type, which can be determined by analysis using X-ray diffraction (XRD) and scanning electron microscopy (SEM). Optimal salinities (and compositions) for mixed low-salinity injection waters for FOR for each segment or area of the reservoir 65 can be determined by correlations of the resulting deterioration in reservoir properties with different salinity breakpoints (and different concentrations of individual ions or individual ions by ion type) for injection water for a range of rock samples with different clay grades and clay compositions, and selecting cut-offs for the salinity (or compositions) of the mixed low-salinity injection water for the rock sample that most closely matches the rock composition (e.g., using historical data) for each pay area Reservoir 65, which is supposed to have a waterflood with low-salinity water. Alternatively, experiments can be carried out on rock samples taken from reservoir regions where injection wells 47 have been drilled using different breakpoints for salinity and composition (individual ion concentrations and individual ion concentrations by ion type) for mixed brackish injection water. , to determine the optimum range for salinity and composition for injection waters to be injected into each segment or area of reservoir 65 in a low-salinity FDT process.

As a rule, the injection capacity for mixed low-salinity water(s) for PNO is limited by the insufficient capacity of the demineralization or water softener unit 30 . Accordingly, a low-salinity waterflood for FOR can be designed to inject a small pore volume (VP) plug of mixed low-salinity injection water into the injection well(s) 47 drilled into the oil-bearing layer of each area of the reservoir 65, in an amount of at least 0.3 pore volume , preferably at least 0.4 pore volume, since plugs having such minimum pore volumes tend to maintain their integrity within the reservoir formation. To limit the amount of water injected into each region of the reservoir from the injection well(s) 47 in embodiments, the pore volume of the mixed low-salinity injection water for the FOR may be less than 1 PO, less than or equal to 0.9 PO, less than or equal to 0.7 PV less than or equal to 0.6 PV, or less than or equal to 0.5 PV.

After injecting mixed low-salinity or softened injection water for low pore volume EOR into the injection well(s) 47 drilled into the segment(s) of the reservoir 65, from the injection well(s) 47 drilled into the oil-bearing layer of the reservoir, can be injected working water to ensure that the plug of mixed low-salinity injection water (and hence the displaced oil zone) moves through the oil-bearing layer of the productive formation 65 to the production well 71 drilled in the oil-bearing layer of the productive formation 65. In addition, the injection of the working water can be used to maintain pressure in the segment(s) or region(s) of the reservoir 65. Typically, the working water has a higher PO than the plug of the aqueous displacement fluid (eg, brackish or softened injection water for EOR).

- 18 042218

As already noted, the working water may be formation water or a mixture of sea water and formation water, depending on the amount of formation water separated from the produced fluids at the field equipment or separator 75. The use/disposal of formation water as working water may be preferred due to restrictions on the disposal of produced water in the ocean. Accordingly, following the injection of a brackish injection water plug into the injection well(s) 47 drilled in the area of the reservoir 65, this well(s) 47 can be used as well(s) for the recovery of formation water.

The flow rate and composition of the mixed brackish or softened ESP injection water stream can be monitored in real time to determine the effectiveness of the changes made by the control unit 90 in mixing to maintain the composition of the mixed brackish or softened ESP injection water within the operating range. If the efficiency is insufficient, the control unit can introduce further changes into the mix. Accordingly, the control unit 90 may have a feedback loop for controlled mixing (eg, to produce RO water, NF water, RW water, MB, or combinations thereof) of the 35C brackish or softened water component stream(s) for EOR.

One or more IW disposal routes with or without re-injection and system components at step 98 of the FIG. 4 may be as described above with reference to FIG. 1-3. In embodiments, the software 92 also allows the dynamic reallocation of one or more injection pumps 60 from the brackish water manifold 45 to the recovery manifold 55, whereby the injection performance capabilities of the brackish water manifold 45 and the recovery manifold 55 can be satisfied. In embodiments, the software uses as input the total production rate of the IW, and if allocating all the IW for disposal via offtake with offloaded oil, overboard, injection into the recovery header 55 through the recycling line and injection into the injection manifold 45 through the mixing line results in a composite low-salinity flow 35C for EOR, having a salinity above the threshold salinity for the purposes of EOR, redistribute one or more segments of the reservoir 65, previously allocated for EOR with soft-salinity waterflood, as a segment for disposal so that the composite soft-salinity 35C flow for FOR in the brackish water line maintains salinity below the threshold salinity or equal to the target salinity, so that FOR with soft water flooding can be continued in the remaining segments of the reservoir 65, identified as segments for low-salinity waterflooding.

Due to the risk of deterioration of reservoir properties during waterflooding with brackish or softened water during FOR, the maximum allowable increase in well pressure for injection well(s) 47/57 drilled in segments of the productive formation 65 can be entered into the control unit 90. pressure in the injection well 47/57, drilled in one of the areas of the reservoir 65, and the drop in flow after the injection pump(s) 60, indicates a decrease in well injectivity due to deterioration of the reservoir properties of the reservoir in one of the segments of the reservoir 65.

The downhole pressure in the injection well(s) 47 near the oil-bearing layer in each segment of the reservoir 65 (or the flow rate of mixed low-salinity or softened injection water after the injection pump(s) of the injection system can be monitored in real time. The pressure of the injection well (in) 47 can be measured downhole measuring device, for example, a pressure sensor, connected to the control unit 90, for example, via a fiber optic telemetry line or using other suitable means of communication.

If the control unit 90 determines that there is a reduction in injectivity for the injection well(s) 47 drilled in one or more areas of the reservoir 65, the control unit may select a different operating range for the composition of the composite injection water stream(s) for the EOR, which, is predicted to be less likely to cause degradation of the reservoir properties (while maintaining an acceptable level of FOR from that reservoir area(s)), and can then adjust the mix ratio of the different blend streams (e.g. brackish or softened water, e.g. ROI permeate and /or NF of permeate in lines 32 and 33, respectively, PV of mixed water in line 84 of mixing) so that the composition of the mixed low-salinity injected water for FOR injected into the injection well(s) 47 drilled into the segment(s) for FOR of the productive formation 65 fell within this other operating range(s). The control unit may continue to monitor, in real time, downhole pressure in the injection well(s) 47 drilled in the region(s) of the reservoir 65 where there has been a decrease in well injectivity (or flow downstream of the injection pump(s) 60 for dedicated injection lines leading to the injection well(s) 47 drilled in the region(s) of the reservoir 65 where injectivity has declined) to determine how the pressure (or flow rate) stabilizes in response to the injection of mixed low-salinity injection water

- 19 042218 for PNO, the composition of which is in the preferred operating range. If this is not the case, the control unit 90 may make further changes to the operation of the mixing system to adapt the composition of the low-salinity or softened water injection component stream(s) for the EOR to another preferred operating range, which, according to calculations, the risk of deterioration of the reservoir properties of the formation is lower. This is an iterative process that can be repeated many times. In some cases, the control unit may decide to reduce the flow of brackish or softened injection water for EOR or stop injection of brackish or softened injection water for EOR into the injection well(s) of one or more areas of the reservoir 65 if the pressure continues to increase. The control unit may also decide to pump a clay stabilizing composition (e.g., an undiluted clay stabilizer concentrate) into the oil-bearing layer(s) of the region(s) of the reservoir 65 in which the well injectivity has declined for a period of several days, before resuming flooding of the low-salinity or softened water for PNO.

Injection of brackish or softened water and IW is affected by the location of the initial injection wells in different segments of the reservoir or reservoir 65. Initially, injection wells in the segment(s) destined for secondary brackish or softened water flooding and wells, and there may be wells allocated for the disposal of HP in the segment(s) intended for the permanent disposal of HP (without any tertiary flooding with brackish or softened water). The various injection wells 47/57 for different segments of the reservoir 65 have typically been drilled sequentially from the platform over an extended period of time. Some segments were developed earlier than other segments. Sufficient water injection into each segment was used to maintain oil production from production wells 71 (eg, to replace pore voids). The experience of the first few wells can provide useful information for distinguishing different segments for secondary or tertiary EOR or disposal, and for dynamic distribution of IW. For example, unexpected pressure reduction features may be encountered that provide information about the hydrodynamic relationship between injector and production wells and facilitate changes in the planned well location. The system for optimizing the distribution of HP, the method and means disclosed herein, provides for the dynamic distribution of HP between disposal procedures with and without reverse injection for the period of use of waterflooding for EOR.

The introduction of brackish or softened water into the recovery manifold 55 via one or more injection pumps 60 is essentially useless, and the system, method, and means disclosed herein for dynamic distribution of IW may allow such a situation to be avoided based on a calculated evaluation of the use of additional injection wells and reservoir segments. 65 to inject brackish or softened water for EOR if there is an excess of brackish or softened water (for example, tertiary injection of brackish or softened water into an injection well or reservoir segment 65 in which the IW was previously injected). If the performance of the HP disposal manifold 55 is exceeded without introducing HP into the low-mineralized or softened water reservoir 45 at a level exceeding the threshold values of the composition range, using the disclosed system, method and means, a numerical evaluation can be carried out by modeling alternative scenarios in which there are no losses in EOR during flooding with low-mineralized or softened water in all segments allocated for EOR. For example, the system, method, and means of the present disclosure may convert one or more formerly EOR segments or wells of a reservoir into a salvage segment or well while maintaining the EOR in the remaining EOR segments.

The private embodiments disclosed above are provided for illustration only, as the present disclosure may be modified and used in other equivalent ways as will be apparent to those skilled in the art having studied the present disclosure. In addition, the design details and solutions described herein are not intended to be limiting in any way other than those described in the appended claims. Therefore, it is obvious that the private embodiments disclosed herein by way of illustration may be changed or modified, and such changes and modifications are contemplated within the scope and spirit of the present disclosure. Alternative embodiments resulting from the combination, addition and/or deletion of features of the embodiment(s) of implementation also fall within the scope of the present disclosure. While compositions and methods are described in broader terms having, consisting of, containing, or including various components or steps, compositions and methods may also consist essentially of, or consist of, various components and steps. The use of the term optional with respect to any element of a claim means that the element is required or, conversely, the element is not required, both alternatives being within the scope of the claim.

The amounts and ranges disclosed above may vary by some amount. Every time a numerical interval with a lower limit and an upper limit is revealed, in particular the disclosure

- 20 042218 Any number and any included interval that fall within this interval are accepted. In particular, each range of values (of the form from about a to about b, or equivalently from about a to b, or equivalently from about a-b) disclosed herein, should be understood as establishing each number and interval contained within the broader range of values . In addition, the terms in the claims have their usual, commonly used meaning, unless otherwise clearly and unambiguously stated by the patent owner. Moreover, the indefinite articles used in a formula are considered to denote one or more of the elements it introduces. If there is any conflict in the use of a word or term in this specification and one or more patents or other documents, the interpretations consistent with this specification should apply.

Embodiments disclosed herein include.

A. A method for dynamically distributing total formation water (TW) from a reservoir during enhanced oil recovery (EOR) through brackish or softened water flooding for EOR, in which: receive measurement data associated with the reservoir, RW and brackish or softened water and containing: the flow rate of withdrawal of HP from the productive formation, the flow rate of injection of low-mineralized or softened water, the range of composition of the injected water and the total flow rate of water injection; receive information describing the reservoir, containing: one or more injection zones for EOR, injection rate for EOR associated with each of one or more injection zones for EOR, one or more disposal injection zones, injection rate in the disposal zone associated with each from one or more injector disposal zones, one or more disposal procedures without re-injection, and a disposal rate without re-injection associated with each of the one or more disposal procedures without re-injection; determining a mixing flow rate comprising at least a portion of the HP withdrawal flow rate and at least a portion of the brackish or softened water injection flow rate to obtain a mixed injection fluid, at which the mixing flow rate maintains the composition of the mixed injection fluid within the injection water composition range; mixing at least a part of the HP with at least a part of brackish or softened water at a mixing rate; and dynamically distributing the HP withdrawal rate among: (a) reinjecting into the reservoir by mixing with brackish or softened water and injecting into one or more injection zones of the EOR, injection into one or more injection disposal zones, and combinations thereof; (b) disposal by one or more disposal procedures without the use of re-injection, or a combination thereof, where dynamic allocation maintains the injection rate for the EOR, the injection rate in the disposal zone, and the disposal rate without re-injection below specified thresholds, ensures that the entire production flow rate of the production of HP is re-injected, and without the use of re-injection and meeting the requirement for complete replacement of pore voids, in which the total amount of water injected in (a) is equal to that required to replace the voids.

B. A system for dynamic distribution of formation water (WW) for disposal in a reservoir during a low-salinity waterflood, including: a storage device that stores a means of dynamic distribution; a processor in communication with the storage device, wherein the dynamic allocation means, when executed by the processor, configures the processor to: receive reservoir data containing a determination of the distribution of one or more reservoir segments as segments for disposal and one or more reservoir segments as segments for waterflooding, and total water withdrawal costs; introducing into the dynamic distribution engine data containing the distribution of one or more reservoir segments and the total withdrawal costs of the IW; preliminary assessment of the structure of enhanced oil recovery (EOR) with low-salinity water flooding by segments for each of one or more segments and the total enhanced oil recovery; numerical evaluation of various procedures and costs of disposal of HP with and without re-injection; and determining, based on preliminary and numerical evaluations, one or more IW routes, comprising: one or more re-injection routes selected from (a) mixing with a brackish water treatment plant for a brackish water flood FSP, for injection in one or more of the segments of the FOR with brackish water flooding; (b) reinjection as reclaimed water into one or more of the segments for disposal; or a combination of these routes, and/or one or more non-reinjection routes containing (c) a shipment as part of the produced oil; (d) discharge, or combinations of these routes, when the costs of disposal of HP through (a), (b), (c), (d) or their combinations are equal to the total cost of withdrawal of HP.

B. A system for simultaneously injecting a brackish water flood and formation water for disposal in a reservoir having multiple segments, comprising: a brackish water preparation system configured to generate a brackish water stream; a separator capable of separating commercial oil for shipment from a field product containing produced oil, the total volume of HP for disposal

- 21 042218 and haa; a brackish water injection manifold having fluid connection via a brackish water line to a brackish water preparation system; a disposal discharge manifold having fluid connection via a disposal line with a separator; one or more injection pumps in fluid communication with the brackish water injection manifold and the disposal injection manifold; a brackish water injection manifold in fluid communication with one or more injection pumps, whereby a brackish EOR stream containing at least a portion of the brackish water stream can be injected into one or more reservoir segments dedicated to the BOR with soft water flooding; a disposal injection manifold in fluid communication with one or more injection pumps, whereby a disposal stream containing at least a portion of the total HP for disposal can be pumped into one or more reservoir segments to be disposed of; a mixing line fluidly connecting the disposal line to the brackish water line, whereby a portion of the entire HP for disposal can be mixed with the brackish water stream to produce a brackish POR stream before it is fed to the brackish water manifold; and a control system comprising a processor with software tools (PS) configured to: determine injection rates per segment in accordance with the requirements for void replacement and injection for EOR, with dynamic allocation of all HP for disposal through one or more reinjection routes, one or more routes without re-injection, or a combination thereof, wherein the one or more re-injection routes are selected from injection into the injection manifold of the disposal through the disposal line, injection into the reservoir of low-salinity water through the mixing line, or a combination of these routes.

Each of Embodiments A, B, and C may have one or more of the following optional elements.

Element 1, in which the amount of HP injected back into the reservoir in procedure (a) is divided between one or more of the procedures: (c) the amount of HP mixed with a brackish or softened water stream to obtain a brackish or softened water flow for EOR, with salinity below the target salinity for FOR and brackish or softened water for FOR introduced as a plug into one or more segments of the productive formation allocated for secondary or tertiary FOR with brackish or softened water flooding; (d) the amount of HP used as and/or flushing fluid that is injected into one or more segments of the productive formation allocated to the low-salinity or softened water EOR after and/or before, respectively, injection of the low-salt or softened water plug into it for PNO; (e) the amount of HP used in the secondary production mode by injecting into one or more reservoir segments allocated to tertiary brackish or softened water for EOR before injection of a plug of brackish or softened water for EOR in the tertiary production mode into it; (e) the amount of HP injected via the disposal stream into one or more reservoir segments designated for HP disposal; (g) the amount of HP mixed with the brackish or softened water stream to produce a brackish or softened FOR water flow having a salinity less than the FOR threshold salinity, and to introduce the brackish or softened FOR water as a plug into one or more reservoir segments, allocated for secondary or tertiary FOR with low-mineralized or softened water flooding; and (h) the amount of HP mixed with the brackish or softened water stream to produce a brackish or softened water for FOR, the salinity of which is above the threshold salinity for FOR purposes, and introduced into one or more segments of the reservoir; moreover, the amounts of HP allocated to each of the procedures from (c), (d), (e), (f), (g) and (h) are maintained below the injection limits for the associated one or more segments, respectively.

Element 2, in which the brackish or softened water plug for FSP has a pore volume less than or equal to about 0.8, 0.7, 0.6, 0.5, 0.4, or 0.3.

Element 3, where, provided that the total amount of HP for distribution is such that the amount of HP in (h) will not be zero, one or more reservoir segments allocated for injection of low-salinity or softened water for FOR is reassigned for disposal so that the amount of SP in (e) can be increased while the amount of SP in (h) remains zero, with the result that the rest of one or more reservoir segments allocated for FOR with low-salinity or softened water flooding can still be supplied with low-salinity or softened water with a mineralization less than the target or threshold for low-mineralized or softened water for PNR by procedures (c) or (g).

Element 4, in which (b) disposal by one or more non-reinjection procedures comprises (i) shipping in produced oil, (j) overboard discharge, or a combination of both.

Element 5, in which the amount of HP in the produced oil for shipment to (i) is kept below the maximum limit for shipment, and in which the amount of HP being dumped overboard in (k) is maintained below maximum limit for overboard discharge.

Element 6, in which, during distribution, the order of distribution of PV is established first in (i), penultimate in (k), last in (h), or a combination of them.

Element 7, in which in (a) the amount of HP injected back into the reservoir contains quantities in (c), (e) (g) and (h), and in which, when distributing water, the order of distribution of water is established in the order (and ), (c), (f), (g), (j), (h).

Element 8, in which the amounts of HP re-injected by procedures (c), (d), (e), (g) and (h) are injected into the associated one or more segments of the productive formation through a low-salinity or softened water manifold for FOR, several injection pumps, and a low-salinity or softened water reservoir for EOR, and in which the amount of HP re-injected by procedure (e) for disposal is injected into one or more segments of the reservoir allocated for disposal, through a disposal manifold, several injection pumps and a disposal manifold .

Element 9, in which several pressure pumps have a fluid connection with a brackish or softened water manifold for EOR and a recovery manifold, and a fluid connection with a brackish or softened water manifold and a recovery manifold.

Element 10, in which the distribution also takes into account the number of reservoir segments available for disposal, the number of reservoir segments available for low-salinity or softened water for EOR, requirements for injection parameters, including target and threshold salinities, flow rates and pore volumes for low-salinity or of soft water for EOR pumped into segments of EOR with brackish or softened water flooding, the capacity of injection pumps for the recovery manifold, the capacity of injection pumps for the brackish or softened water for EOR manifold, the capacity of the brackish or softened water header, the capacity of the recovery header, or a combination of them.

Element 11, if the distribution in order of priority of procedures (i), (c), (f), (g), (k), (h) will exceed the capacity of the injection pump for the low-mineralized or softened water manifold, injection of low-mineralized or softened water from it will be reduced if, during distribution in the order of priority (i), (c), (f), (g), (k), (h), the capacity of the injection pumps for the disposal manifold is exceeded, the injection of recycled water from it will be reduced, or these abbreviations will be combined.

Element 12, if during the distribution in the order of priority (i), (c), (e), (g), (k), (h) the performance of the low-mineralized or softened water collector for the FSP is exceeded without exceeding the performance of the first subgroup of injection pumps, pumping water into it, one or more segments of the reservoir are switched to a brackish or softened water reservoir for EOR, while one or more segments are switched from use for disposal to distribution for brackish or softened water for EOR, to provide additional injection capacity; if, during the distribution in order of priority (i), (c), (f), (g), (k), (h), the capacity of the utilization collector is exceeded without exceeding the capacity of the remaining injection pumps pumping water into it, one or more segments of the reservoir is switched to a disposal manifold from a brackish or softened water for EOR, wherein one or more segments are switched from use for brackish or softened water for EOR to distribution for disposal, to provide additional injection capacity; or these reallocations will be combined.

Element 13, in which the discharge of HP overboard in the procedure (i) includes the processing of the HP to be discharged to remove oil from it.

Element 14, in which the brackish or softened water is brackish water obtained by reverse osmosis (RO), nanofiltration, or a combination thereof, or softened water obtained by nanofiltration, precipitation of hardness ions, ion exchange, or a combination of these methods.

Element 15, in which at least part of the softened water is obtained from HP.

Element 16, in which the data further includes the capacity of the brackish flow generated by the brackish liquid preparation plant, the number of injection pumps available to inject brackish water for the EOR from the brackish water for the EOR or waste water from the disposal manifold into the brackish water for the EOR, the number of injection pumps pumps available for pumping low-salinity water from the low-salinity water for ESP manifold or waste water from the recovery manifold into the recovery manifold, the maximum capacity of the individual pump, the minimum allowable pump flow, the target salinity of the injection low-salinity water for the ESP, the maximum acceptable or threshold salinity for low-salinity water for EOR, delay of formation water parameters due to EOR with low-salinity water flooding, plug size is weak of unsalted water for FSP as a fraction of pore volume (PV) for each segment of FSP with brackish water flooding, SW of each segment, start date for injection of SW or brackish water for FSP for each segment, start date for FSP with brackish water flooding for each segment, or a combination thereof, and in which the processor generates output data characterizing the operation of the brackish liquid preparation device, the flow rates and salinity in the injection header, the use of the injection pump and the brackish liquid preparation device, injection rates by segments, or a combination of these data.

Element 17, in which the processor determines three modes of pump use: the first, or good mode, indicating that each of the injection pumps is for one of the low-salt water for the EOR or the disposal manifold; a second, or acceptable mode, indicating that the injection pump is designed to inject brackish water for ESP into both the brackish water for ESP and the disposal manifold; and a third or unacceptable mode, indicating that the injection pump is designed to inject brackish water for EOR into the brackish water for EOR and recycled water into the disposal manifold.

Element 18, additionally containing an increase or decrease in injection in one or more segments to obtain the first or second mode for each of the injection pumps.

Element 19, wherein if the processor indicates that an excess amount of brackish water is being directed to the recovery reservoir, one or more additional reservoir segments can be allocated as segments for the BSA waterflood due to the occurrence of such an excess of brackish water for the BSA.

Element 20, in which the processor seeks to fulfill the following conditions, in addition to maintaining the condition that the sum of the disposal costs in procedures (a), (b), (c) and (d) is equal to the total flow rate of withdrawal of HP: the total flow rate of water injection into one or more segments for EOR in (a) and one or more disposal segments in (b) is greater than or equal to the estimated IW re-injection rate equal to the predicted total IW withdrawal rate minus the IW disposal costs in (c) and (d); the total salinity of the low-salinity water flow for FSP is equal to the target salinity; the level of salinity in the low-salinity water reservoir for FOR is below the threshold mineralization for FOR; the performance of the brackish water preparation device is sufficient to generate a stream of brackish water; the number of booster pumps required does not exceed the total number of booster pumps available; each of the injection pumps is used with a flow rate that exceeds the minimum allowable injection flow rate; discharges and mineralizations are above or equal to zero, or a combination of these conditions.

Element 21, in which the low-salinity flow and SW are distributed between the low-salinity water reservoir for EOR and the disposal header, and the SW re-injected by (a) or (b) is mainly sent to the recovery header for disposal by procedure (b), and the low-salinity water, generated in the brackish liquid preparation plant is predominantly sent to the brackish water collector for mixing, as a brackish water flow for the FSP, as in (a).

Element 22, in which the installation for the preparation of low-mineralized liquid contains one or more reverse osmosis (RO) modules, and in which the processor takes into account the water production capacity of the RO by the RO module and the number of available modules 00.

Element 23, in which RO water is preferably miscible with HP, as in (a), is miscible with nanofiltration water (NF) in the absence of HP, for example, in the initial stages of the INR or in both cases.

Element 24, used to develop soft water EOR equipment, or to analyze and/or redistribute IW disposal procedures, reservoir segments as soft water EOR or salvage segments or both within existing soft water EOR equipment .

Element 25, in which the processor calculates the salinity of the low-salinity water for the injection ESP as in (a) and the salinity of the utilized water, and in which one or more segments allocated for injection of the low-salinity water for the ESP are reallocated for disposal, if the calculation indicates that the mixed water in (a) has a salinity above the target salinity, or above the threshold salinity for FSP purposes.

Element 26 wherein one or more non-reinjection routes are selected from produced oil shipment, overboard discharge, or a combination thereof.

An element 27 further including an IW treatment system containing an oil removal device used to reduce the oil concentration in the IW to a level below or equal to about 40 ppm oil in water.

- 24 042218

Element 28, in which the brackish water production system includes reverse osmosis, nanofiltration, hardness ion precipitation, ion exchange, or a combination thereof.

Element 29 in which the salinity of the brackish water stream is less than or equal to about 300 ppm and the brackish water stream for FSP has the target salinity

1500 ppm or both.

Element 30, in which by introducing HP into the low-salinity water collector through the mixing line, a low-salinity water flow is obtained for FSP with a salinity less than the target salinity.

Element 31, in which the target mineralization is 1500 ppm.

Element 32, wherein the software also dynamically allocates one or more injection pumps from the brackish water manifold to the recovery manifold, whereby the requirements for the injection performance of the brackish water reservoir and the injection performance of the recovery manifold can be met.

Element 33, in which the software takes as input the total flow rate of the extraction of IW and, if the distribution of all IW for disposal through shipment with produced oil, discharge overboard, injection into the disposal header through the disposal line, and injection into the injection manifold of low-salinity water along the mixing line results in a composite low-salinity water flow for FOR with a salinity above the threshold salinity for the purposes of FOR, redistributing one or more segments of the productive reservoir previously allocated for FOR with soft-salinity waterflooding as a segment for disposal so that the composite flow of soft-salinity water for FOR in the brackish water line maintains salinity below the threshold salinity level or equal to the target salinity, while FOR with soft water flooding can be continued in the remaining segments allocated as segments for low-salinity water flood.

While some embodiments have been shown and described, modifications may be made by those skilled in the art without departing from the principles of this disclosure.

Many other modifications, equivalents, and alternatives will be apparent to those skilled in the art upon careful reading of the above disclosure. The following formula is intended to be taken to cover these modifications, equivalents and alternatives where applicable. Accordingly, the scope of protection is not limited to the above description, but only to the following claims, the scope of which includes equivalents of subject matter according to the claims.

Claims (25)

CLAIM 1. A method for dynamic distribution of the total amount of formation water (PV) from a productive formation during enhanced oil recovery (EOR) using low-mineralized or softened water flooding for EOR, during which measurement data associated with the reservoir, SW and low-mineralized or softened water are taken, and including: the flow rate of the withdrawal of HP from the productive formation, the flow rate during injection of low-mineralized or softened water, the range of composition of the injected water and the total flow rate of water injection; receive information about the parameters of the reservoir, including: one or more injection zones of the FOR, the injection rate for the FOR associated with each of one or more injection zones of the FOR, one or more zones of utilization injection, the injection rate in the zone of utilization injection associated with each of one or more disposal injection zones, one or more disposal procedures without re-injection, and a disposal rate without re-injection associated with each of the one or more disposal procedures without re-injection; determining a mixing flow rate, including at least a portion of the HP withdrawal flow rate and at least a portion of the brackish or softened water injection flow rate, to obtain a mixed injection fluid, the mixing flow rate maintaining the composition of the mixed injection fluid in the injection water composition range; mixing at least a part of the HP with at least a part of brackish or softened water at said mixing rate; and dynamically distribute the flow rate of extraction of HP between: (a) reinjecting into a reservoir by mixing with brackish or softened water and injecting into one or more EOR injection zones, injecting into one or more disposal injection zones, or a combination thereof; (b) disposal by one or more disposal procedures without re-injection, or a combination thereof, wherein dynamic distribution maintains the injection rate at FOR, the injection rate in the disposal zone, and the disposal rate without re-injection below specified thresholds, provides - 25 042218 Utilization of the entire IW withdrawal flow with or without re-injection, and provides the total void replacement flow when the total amount of water pumped back in step (a) meets the void replacement requirements. 2. The method of claim 1 wherein the amount of HP injected back into the reservoir in step (a) is divided among one or more of: (c) the amount of HP mixed with the brackish or softened water stream to produce a brackish or softened FOR water stream having a salinity below the FOR target salinity and introduced as a brackish or softened FOR water plug into one or more reservoir segments, allocated for secondary or tertiary FOR with low-mineralized or softened water flooding; (d) the amount of HP used as a working and/or flushing fluid injected into one or more segments of the productive formation allocated for FOR with brackish or softened water flooding after and/or before, respectively, injection of a plug of brackish or softened water therein for PNO; (e) the amount of IW used in the secondary production mode with injection into one or more segments of the productive formation allocated for the tertiary FOR with the injection of low-salinity or softened water, before the injection of the plug of low-salinity or softened water there for the FSP in the tertiary production mode; (e) the amount of HP injected via the disposal stream into one or more reservoir segments designated for HP disposal; (g) the amount of HP mixed with the brackish or softened water stream to produce a brackish or softened FOR water flow having a salinity less than the FOR threshold salinity and introduced as a plug of brackish or softened FOR water into one or more reservoir segments, allocated for secondary or tertiary FOR with low-mineralized or softened water flooding; and (h) the amount of HP mixed with the brackish or softened water stream to produce a brackish or softened water for FOR having a salinity above the threshold salinity for FOR and injected into one or more reservoir segments; moreover, the amounts of HP allocated for each of the procedures (c), (d), (e), (f), (g) and/or (h) are maintained below the injection limits for the associated one or more formation segments. 3. A method according to claim 2, wherein the brackish or softened water plug for the FSP has a pore volume less than or equal to about 0.8. 4. The method of claim 2, wherein in procedure (b) disposal by one or more non-reinjection procedures comprises (i) shipping as produced oil, (j) overboard, or a combination of these procedures. 5. The method according to claim 4, wherein the distribution is prioritized by the distribution of PVs first by procedure (i), penultimately by procedure (k), last by procedure (h), or a combination thereof. 6. The method according to claim 4, wherein in procedure (a) the amount of HP injected back into the reservoir contains the amounts according to (c), (e), (g) and (h), and the distribution of water is prioritized in order (i), (c), (f), (g), (k), (h). 7. The method of claim 4, wherein the quantities of HP injected back in procedures (c), (d), (e), (g), and (h) are injected into the associated one or more reservoir segments through a brackish or of softened water for EOR, several injection pumps and a brackish or softened water for EOR, and the amount of HP pumped back through procedure (e) for disposal is injected into one or more segments of the productive formation allocated for disposal through a disposal manifold, several injection pumps and a disposal manifold. 8. The method of claim 7 wherein the plurality of pressure pumps are in communication with a brackish or softened water EOR manifold and a recovery manifold, and are in communication with a brackish or softened water manifold and a recovery manifold. 9. The method according to claim 7, in which the distribution additionally takes into account the number of reservoir segments available for disposal, the number of reservoir segments available for FOR with low-mineralized or softened water, requirements for injection parameters, including target and threshold salinities, costs and pore volumes for brackish or softened water for EOR injected into EOR segments with brackish or softened water flooding, delivery pump capacity for recovery manifold, injection pump capacity for brackish or softened water for EOR, header capacity for brackish or softened water, recovery header capacity , or combinations thereof. - 26 042218 10. The method of claim 1, wherein the brackish or softened water is brackish water obtained by reverse osmosis (RO), nanofiltration, or a combination thereof, or softened water obtained by nanofiltration, precipitation of hardness ions, ion exchange, or a combination thereof. 11. The method according to claim 10, in which at least part of the softened water is obtained from HP. 12. System for the dynamic distribution of formation water (W) for disposal in the reservoir during waterflooding with brackish water, including a storage device that stores the means of dynamic distribution; and a processor in communication with the storage device, the dynamic allocation means, when executed by the processor, configuring the processor to receive reservoir data containing a determination of the distribution of one or more reservoir segments as disposal segments and one or more reservoir segments as segments for waterflooding during EOR, and total withdrawal costs of IW; entering into the dynamic distribution engine data containing the distribution of one or more reservoir segments and the total recovery rates of the IW; a preliminary assessment of the characteristics of enhanced oil recovery (EOR) with low-salinity water flooding by segments for each of one or more segments and the overall enhanced oil recovery; numerical evaluation of various procedures and costs of disposal of HP with and without re-injection; and determining, based on said preliminary and numerical evaluations, one or more IW routes comprising: one or more re-injection routes selected from (a) mixing with a brackish stream produced by a brackish fluid preparation unit for a brackish water flood, for injection into one or more segments of the EOR with brackish water flooding; (b) reinjection as reclaimed water into one or more of the segments for disposal; or a combination of these routes, and/or one or more non-reinjection routes containing (c) a shipment as part of the produced oil; (d) discharge, or a combination of these routes, when the costs of disposal of HP through operations (a), (b), (c), (d) or their combination are equal to the total flow rate of withdrawal of HP, and at least part of the HP is mixed with flow of brackish water and injected into one or more segments of the FSP of the brackish water flood. 13. The system according to claim 12, in which the distribution of the low-salinity flow and HP between the reservoir of low-salinity water for EOR and the disposal manifold is ensured, and the HP, injected back in procedures (a) and (b), is directed primarily to the disposal manifold for disposal by procedure (b), and preferentially directing the brackish water produced in the brackish liquid preparation plant to the brackish water manifold for mixing as a brackish water flow for the EOR, as in procedure (a). 14. The system of claim 12, wherein the brackish liquid preparation unit comprises one or more reverse osmosis (RO) modules, and the processor is configured to take into account the water generation capacity of the RO in the RO module and the number of RO modules available. 15. A system according to claim 14, wherein the preferred mixing of RO water with HP as in procedure (a), and mixing with nanofiltration water (NF) in the absence of HP, as in the initial stages of the FNR, or in both cases. 16. The system of claim 12, used to develop equipment for a soft water EOR or to analyze and/or redistribute procedures for the disposal of IW, reservoir segments as segments for a soft water EOR or disposal segments, or both within an existing equipment for EOR with low-mineralized waterflooding. 17. The system of claim 12, wherein the processor is configured to calculate the salinity of the brackish water for the injection ESP as in procedure (a) and the salinity of the utilized water, and one or more of the segments dedicated to the injection of the brackish water for the ESP are reallocated to disposal, if the numerical assessment shows that the mixed water in procedure (a) has a salinity above the target salinity or above the threshold salinity for the EOR. 18. A system for simultaneously injecting brackish water flooding and formation water (PW) for disposal in a reservoir having several segments, including a system for preparing brackish water, configured to generate a flow of brackish water; a separator configured to separate commercial oil for shipment from the field product containing the produced oil, the total amount of HP for disposal and gas; - 27 042218 injection manifold of brackish water, communicating via a line of brackish water with a system for preparing brackish water; a recovery manifold in communication with a separator through a recovery line; one or more injection pumps in communication with the brackish water injection manifold and the disposal injection manifold; a brackish water injection manifold in communication with one or more injection pumps, whereby a brackish FOR stream containing at least a portion of the brackish water stream can be injected into one or more reservoir segments dedicated to the FOR with brackish water flooding; a disposal injection manifold in communication with one or more injection pumps, whereby a disposal stream containing at least a portion of the total HP for disposal can be pumped into one or more segments of the productive formation allocated for disposal; a mixing line connecting the disposal line to the brackish water line, whereby a portion of the entire HP for disposal can be mixed with the brackish water stream to obtain a brackish stream for the EOR before it is supplied to the brackish water manifold; and a system as set forth in claim 12 for dynamically allocating the HP for disposal in the reservoir, wherein the processor has software configured to determine injection rates for a segment that satisfies the void replacement and injection requirements for the EOR, while dynamically allocating all of the HP for disposal through one or more re-injection routes, one or more non-re-injection routes, or a combination thereof, wherein (a) includes introducing brackish water into the reservoir through a mixing line, and (b) includes introducing into a recovery injection header through a disposal line. 19. The system of claim 18, wherein one or more non-reinjection routes are selected from produced oil shipment, overboard discharge, or a combination of these routes. 20. The system of claim 18, further comprising an IW treatment system comprising an oil removal device used to reduce the concentration of oil in the IW to less than or equal to about 40 ppm oil in water. 21. The system of claim 18, wherein the brackish water preparation system includes reverse osmosis, nanofiltration, hardness ion precipitation, ion exchange, or a combination thereof. 22. The system of claim 21, wherein the brackish water stream has a salinity of less than or equal to about 300 ppm, wherein the brackish water stream for the EOR has a target salinity of 1500 ppm, or both. 23. The system of claim 18, wherein the introduction of HP into the brackish water reservoir through the mixing line provides a brackish flow for the FOR with a salinity below the target salinity. 24. The system of claim 18, wherein the software further provides for dynamic allocation of one or more injection pumps from the brackish water reservoir to the recovery manifold, whereby the requirements for the injection performance of the brackish water reservoir and the injection performance of the recovery manifold can be met. 25. The system according to claim 18, which provides for the reception by software, as input, of data on the total flow rate of extraction of HP and, in the event that the distribution of all HP for disposal through shipment with produced oil, discharge overboard, introduction into the disposal manifold through the disposal line and the introduction of low-salinity water into the injection manifold through the mixing line results in a composite flow of low-salinity water for FOR with salinity above the threshold mineralization for FOR purposes, redistribution of one or more segments of the productive formation previously allocated for FOR with low-salinity waterflooding is provided as segment for disposal so that the composite flow of low-salinity water for FSP in the low-salinity water line maintains salinity below the threshold level of salinity or equal to the target salinity, while FSP with low-salinity waterflooding can be continued in the remaining segments, highlighted nyh as segments for low-salinity waterflooding.