• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    improved method of placing and diverting fluid in underground formations, improved methods of placing and diverting treatment fluids in underground formations are provided. in one embodiment, the methods comprise: introducing a bypass material (14) into an underground formation penetrated by a well bore, to reduce or prevent the flow of fluid into a first part (20) of the underground formation ; introducing a first fluid (16) into a second part (30) of the underground formation having a higher resistance to fluid flow than the first part (20) of the underground formation; allowing the bypass material (14) to be removed from the underground formation after at least a part of the first fluid (16) has been introduced into the second part (30) of the underground formation; and introducing a second fluid (40) into the first part (20) of the underground formation.
    公开号:BR112012004707B1
    申请号:R112012004707
    申请日:2010-08-27
    公开日:2019-12-31
    发明作者:Gualtieri Danial；Glasbergen Gerard；D Welton Thomas
    申请人:Halliburton Energy Services Inc；
    IPC主号:
    专利说明:

    “METHOD OF FLUID PLACEMENT AND DEVIATION IN UNDERGROUND FORMATIONS”
    BACKGROUND OF THE INVENTION [0001] The present invention relates to methods that can be useful in the treatment of underground formations and, more particularly, to improved methods of placing and diverting fluid in underground formations.
    [0002] Treatment fluids can be used in a variety of underground treatments. As used herein, the term "treatment" or "treating" refers to any underground operation that uses a fluid in conjunction with a desired function and / or for a desired purpose. The terms "treatment" and "treating" as used herein do not involve any particular action by the fluid or any particular component thereof. Examples of common underground treatments include but are not limited to drilling operations, pre-lining treatments, fracture operations, drilling operations, pre-flow water treatments, after-water treatments, sand control treatments (eg ., filling with gravel), acidifying treatments (eg matrix acidification or fracture acidification), fractionation-filling treatments, cementation treatments, water control treatments, fluid loss control treatments (e.g. gel pills) and well-hole emptying treatments.
    [0003] In underground treatments, it is often desired to treat an interval of an underground formation having sections of variables permeability, porosity, damage and / or reservoir pressures and, thus, one can accept varying amounts of certain treatment fluids. For example, low reservoir pressure in certain areas of an underground formation or a rocky matrix or high porosity bracing filling may allow part to accept greater amounts of certain treatment fluids. It may be difficult to obtain uniform distribution of the treatment fluid over the entire interval. For example, the
    Petition 870190078437, of 13/08/2019, p. 7/28 / 18 treatment may preferably enter parts of the range with low resistance to fluid flow at the expense of parts of the range with higher resistance to fluid flow. In some instances, these intervals with variable flow resistance may be water-producing intervals. In other examples, the part of a gap with low resistance to fluid flow may be an elbow or curve in a well hole, into which the treatment fluid can preferably enter. In still other examples, the part of a gap with low resistance to fluid flow can be a junction of a multi-lateral well, into which the treatment fluid can preferably enter.
    [0004] In conventional methods of treating such underground formations, once the parts with the least resistance to the flow of an underground formation have been treated, that area can be sealed using a variety of techniques to divert treatment fluids to more resistant to fluid flow in the range. Such techniques may have involved, among other things, the injection of particulates, foam, buffers, shutters or blocking polymers (eg, cross-linked aqueous gels) within the range, in order to substantially buffer the highly permeable parts of the formation underground once they have been treated, thereby subsequently diverting the injected fluids to parts more resistant to fluid flow from the underground formation.
    [0005] Although these diversion techniques have been used successfully, there can be disadvantages. For example, in many cases, at least some of the bypass material may be inadvertently placed on the most fluid flow resistant part of the underground formation, which can prevent or prevent the complete treatment of that part. In addition, in instances where a less fluid-resistant part of the formation has been fractured, certain types of bypass agents (eg, particulates) may not be able to effectively seal the area without using large
    Petition 870190078437, of 13/08/2019, p. 8/28 / 18 volumes of the bypass agent, which can be expensive to install and / or difficult to remove.
    SUMMARY OF THE INVENTION [0006] The present invention relates to methods that can be useful in the treatment of underground formations and, more specifically, to improved methods of placing and / or diverting treatment fluids in underground formations.
    [0007] In one embodiment, the methods of the present invention comprise: introducing a bypass material into an underground formation penetrated by a well bore, to reduce or prevent the flow of fluid into a first part of the formation underground; introducing a part of a first fluid into a second part of the underground formation having a higher resistance to fluid flow than the first part of the underground formation; allowing the bypass material to be removed from the underground formation after at least part of the first fluid has been introduced into the second part of the underground formation; and introducing a part of a second fluid into the first part of the underground formation.
    [0008] In another embodiment, the methods of the present invention comprise: introducing a bypass material into an underground formation penetrated by a well bore to reduce or prevent the flow of fluid into a first part of the underground formation; introducing a part of a first fluid into a second part of the underground formation having a higher resistance to fluid flow than the first part of the underground formation; allowing the bypass material to be removed from the underground formation after at least part of the first fluid has been introduced into the second part of the underground formation; and introduce a part of a second fluid into the first part of the underground formation at a rate sufficient to create or increase
    Petition 870190078437, of 13/08/2019, p. 9/28 / 18 one or more fractures in the first part of the underground formation.
    [0009] In another embodiment, the methods of the present invention comprise: (a) introducing a first bypass material into an underground formation penetrated by a well bore, to reduce or prevent the flow of fluid into a first part of the underground formation; (b) determining when the first bypass material has reduced or prevented the flow of fluid within a first part of the underground formation; (c) introducing a part of a first fluid into a second part of the underground formation having a higher resistance to fluid flow than the first part of the underground formation; (d) introducing a second bypass material into an underground formation penetrated by a well bore, to reduce or prevent the flow of fluid into the second part of the underground formation; (e) introducing a part of a second fluid into the first part of the underground formation at a first flow rate; (f) allow the first diversion material to be removed from the underground formation; (g) determine when the first bypass material has been at least partially removed from the underground formation by monitoring the temperature in that part of the underground formation; and (h) introducing a second fluid within the first part of the underground formation.
    [00010] The aspects and advantages of the present invention will be readily apparent to those skilled in the art. Although numerous changes can be made by those skilled in the art, such changes are within the scope of the invention.
    BRIEF DESCRIPTION OF THE DRAWINGS [00011] These drawings illustrate certain aspects of some of the embodiments of the present invention and should not be used to limit or define the invention.
    [00012] Figures 1 - 8 illustrate a series of steps carried out in
    Petition 870190078437, of 13/08/2019, p. 10/28 / 18 an embodiment of the methods of the present invention.
    DESCRIPTION OF THE PREFERRED EMBODIMENTS [00013] The present invention relates to methods that may be useful in the treatment of underground formations and, more specifically, to improved methods of placing and / or diverting treatment fluids in underground formations.
    [00014] The methods of the present invention generally comprise: introducing a bypass material into an underground formation penetrated by a well bore, to reduce or prevent the flow of fluid in a first part of the underground formation; introducing a first fluid into a second part of the underground formation having a higher resistance to fluid flow than the first part of the underground formation; allowing the bypass material to be removed from the underground formation after at least part of the first fluid has been introduced into the second part of the underground formation; and introducing a second fluid within the first part of the underground formation. The term “diversion material”, as used herein, means and generally refers to a material that works to reduce or prevent, temporarily or permanently, the flow of a fluid into a particular location, usually located in an underground formation , in which the material serves to at least partially obstruct the location and thereby cause the fluid to “deviate” to a different location. The term "fluid flow resistance" is used here to refer to the decrease in the rate at which the fluid will flow into and / or through an area at a fixed injection rate. As used herein, "fluid flow resistance" can result from low connective porosity of a portion of a formation and / or the reduced ability of a portion of a formation to accept or transmit fluids, for example, due to higher reservoir pressure . For example, the low reservoir pressure in certain areas of an underground formation or a rock matrix or
    Petition 870190078437, of 13/08/2019, p. 11/28 / 18 high porosity can allow part of a formation to accept larger quantities of certain treatment fluids and, thus, reduce its “resistance to fluid flow”. Another factor that can affect the “fluid flow resistance” of a part of an underground formation may be low permeability in certain areas of an underground formation or the rock matrix may allow a part of a rock formation or matrix to accept greater quantity of certain treatment fluids and thereby reduce their “resistance to fluid flow”.
    [00015] The methods of the present invention are generally used to treat underground formations having parts of different resistances to fluid flow. In some instances, these parts with varying resistance to fluid flow may comprise water producing intervals. In other examples, a part of an underground formation with low resistance to fluid flow may comprise an elbow or curve in a well into which the treatment fluid can preferably enter. In still other embodiments, the part of an underground formation with low resistance to fluid flow can be a junction of a multilateral well bore into which the treatment fluid can preferably enter. Among the many advantages of the present invention, some of which are not alluded to here, in certain embodiments the methods of the present invention can facilitate improved control in relation to placing the treatment fluids in an underground formation, increased fluid efficiency by several underground treatments and / or more complete treatment of parts resistant to fluid flow of an underground formation.
    [00016] The underground formation treated in the methods of the present invention can be any underground formation having at least two parts of different resistances to fluid flow. At least part of the underground formation is usually penetrated by one or more of the well holes drilled in any direction through the formation. In certain ways
    Petition 870190078437, of 8/13/2019, p. 12/28 / 18 of completion, all or part of the well penetrating underground formation can include tubes or columns of casing tubes placed inside the well hole (a “coated hole” or a “partially coated hole”), among other purposes , to facilitate the production of fluids out of the formation and through the well to the surface. In other embodiments, the well may be an “open hole”, which has no coating. In those embodiments where the well is a coated or partially coated bore, it may be necessary to create perforations in the casing tube column before or during a method of the present invention, inter alia, to allow fluid communication between the interior of the cladding and the adjacent part of the underground formation. These perforations may be made by any means or technique known in the art. In certain embodiments, where a coating is perforated, it may be desirable to perforate the coating with a higher drilling density in the area adjacent to a part or parts of the underground formation having a higher resistance to fluid flow, among other reasons, to increase the flow of fluid to that part. [00017] The by-pass material (s) used in the present invention may comprise any material or combination of materials that work to reduce or prevent, temporarily or permanently, the flow of fluid into a particular location of an underground formation, in which the material serves to at least partially obstruct the location and, thus, cause the fluid to “deviate” to a different location. Examples of materials that may be suitable for use as a bypass material in the present invention include, but are not limited to, fluids (e.g., aqueous-based and / or non-aqueous-based fluids), emulsions, gels ( including but not limited to viscoelastic surfactant gels), surfactants (eg, soap or viscoelastic surfactants), foams, particulate materials (eg, calcium carbonate, silica flour), certain polymers, relative permeability modifiers, degradable materials (eg, polyesters, orthoesters,
    Petition 870190078437, of 8/13/2019, p. 13/28 / 18 poly (orthoesters), polyanhydrides, polylactic acid, dehydrated organic or inorganic compounds, anhydrous borate, salts of organic acids or any derivative thereof, resins (eg water-soluble resins, oil-soluble resins) etc.), balls, plugs (eg, localized point plugs and selective injection plugs), ball plugs, pack-off devices, sand plugs, bridge plugs and the like. "Degradable materials" include those materials that are capable of undergoing irreversible degradation in the hole below. The term "irreversible", as used herein, means that the degradable diversion agent, once degraded, should not be recrystallized or reconsolidated while in the hole below, e.g. eg, the degradable bypass agent must degrade in situ but must not recrystallize or reconsolidate in situ. The terms "degradation" or "degradable" refer to both of the two relatively extreme cases of hydrolytic degradation that the degradable bypass agent may experience, e.g. mass erosion and surface erosion, and any stage of degradation in the middle of these two. This degradation can be a result of, inter alia, a chemical or thermal reaction, or a radiation-induced reaction. The term "derivative" is defined here as including any compound that is made from one of the listed compounds, for example, replacing an atom of the listed compound with another atom or groups of atoms, rearranging two or more atoms of the listed compound, ionizing the listed compounds or by creating a salt of the listed compound. Examples of commercially available materials that may be suitable bypass materials in the methods of the present invention include those products available under the trade names GUIDON SM AGS, BIOVERT ™, baracarb (R) , OSR 100 TM and MATRISEAL (R) , all available from Halliburton Energy Services of Duncan, Oklahoma. Other examples of bypass materials that may be suitable for use in the methods of the present invention can also include those described in US Patent Nos. 6,983,798 and 6,896,058 and US Patent Application No. 12 / 501,881 (filed on 13
    Petition 870190078437, of 13/08/2019, p. 14/28 / 18 July 2009), all of which are incorporated herein by reference. [00018] The choice of a diversion material, including the desired size and shape of any particulate diversion material, in the methods of the present invention, may depend, among other factors, on the type of underground formation (e.g., characteristics of the underground formation). rock), the presence or absence of a coating in the underground formation, the composition of the treatment fluid (s) to be used, the temperature of the underground formation, the size of the perforations, the desired moment and rate of its removal and any subsequent treatments to be carried out following the method of the present invention. For example, if the bypass material is to be placed in a part of a well that is not coated, a bypass material should be chosen that is capable of forming a filter cake on the inner wall of the well hole. In other embodiments, the particle size of a particulate bypass material can be selected so that the fluid permeability of those particles in a package is relatively low. A person skilled in the art will recognize suitable and / or preferred materials for the bypass materials for a particular application of the present invention with the benefit of this description, in view of these and other factors.
    [00019] The diversion material used in the present invention (i.e., the diversion material used to reduce or prevent the flow of fluid into the less fluid-resistant part of the underground formation) must be degradable, dissolvable or otherwise removable by some means known in the art. In certain embodiments, this bypass material can be selected as a material that degrades or dissolves in the presence of the fluid used to treat the fluid-less resistant part of the underground formation (or a component thereof) and / or an intermediate fluid introduced into the formation after the most fluid flow resistant part of the formation has been treated. In certain embodiments, the
    Petition 870190078437, of 13/08/2019, p. 15/28 / 18 bypass can be selected as a material that is simply removed during the passage of time.
    [00020] In certain embodiments, a second bypass material can optionally be introduced into the underground formation, among other purposes, to reduce or prevent the flow of fluid into the most flow resistant part of the underground formation after at least at least part of the first fluid has been introduced into that part of the underground formation. In certain embodiments, the optional second bypass material can be chosen so that it does not degrade, dissolve substantially, or is otherwise removed by the fluid used to treat the less fluid resistant part of the underground formation, or does not degrade or dissolves substantially, or is otherwise removed by that fluid within a particular period of time allotted for treatment. However, such a second bypass material can be otherwise removable (e.g., removable after a long period of time), even though it is not removable under the conditions set out above. For example, if an aqueous fluid is used to treat a fluid flow resistant part of the underground formation, then it may not be desirable to use a second bypass material that degrades or dissolves in the presence of water, such as acid polylactic. A person skilled in the art with the benefit of this description will recognize suitable diversion materials for such uses depending on, among other things, the fluids being used, the time of treatment, the conditions of the training being treated and other factors.
    [00021] The first and second fluids used in the methods of the present invention can comprise any forming fluid or treatment fluid used or found in underground formations or treatments. As used herein, the term "treatment fluid" refers generically to any fluid that can be used in an underground application in conjunction with a desired function and / or for a desired purpose. THE
    Petition 870190078437, of 13/08/2019, p. 16/28 / 18 the expression “treatment fluid” does not imply any particular action by the fluid or any compound thereof. These fluids can be used to perform one or more underground treatments or operations, which may include any underground treatment or operation known in the art. Examples of common underground treatments include but are not limited to drilling operations, pre-trim treatments, fracture operations, drilling operations, pre-flood treatments, post-flood treatments and control treatments (eg, gravel filling) ), acidifying treatments (eg matrix acidification or fracture acidification), filling-fractionation treatments, cementation treatments, water control treatments and well emptying treatments.
    [00022] Depending on the type of treatment to be performed, the fluid can comprise any treatment fluid known in the art. Examples of treatment fluids that may be suitable include fracturing fluids, gravel filling fluids, pre-trim fluids, trim fluids, pre-flood fluids, post-flood fluids, acid fluids, consolidation fluids, cementation fluids, fluids well hole emptying, forming fluids, aqueous fluids (eg fresh water, salt water, brines etc.), non-aqueous fluids (eg mineral oils, synthetic oils, esters etc.), hydrocarbon-based fluids (eg, kerosene, xylene, toluene, diesel, oils etc.), foamed fluids (eg, a liquid comprising a gas), gels, emulsions, gases and the like. The fluids used in the present invention can optionally comprise one or more of any additives known in the art, as long as such additives do not interfere with other components of the fluid or other elements present during its use. Examples of such additional additives include but are not limited to salts, soaps, surfactants, co-surfactants, carboxylic acids, acids, less fluid control additives, gas, foaming agents, corrosion inhibitors, scale inhibitors, crosslinking agents, catalysts ,
    Petition 870190078437, of 13/08/2019, p. 17/28 / 18 clay control agents, biocides, friction reducers, anti-foaming agents, bridging agents, dispersants, flocculants, H2S purifiers, oxygen purifiers, lubricants, viscosifiers, breakers, weighing agents, permeability modifiers relative, resins, particulate materials (eg, propping particles), wetting agents, coating enhancing agents and the like. A person skilled in the art with the benefit of this description will recognize the types of additives that can be included in the fluids for a particular application.
    [00023] In certain embodiments, the second fluid can be used not only to treat a less fluid-resistant part of the underground formation, but can also be used to remove at least part of the bypass material used to bypass fluid , while the most fluid resistant part (s) is / are treated. In embodiments where the second fluid is used in this way, the second fluid can be introduced initially at a lower flow rate or with a short initial stage, followed by a significant reduction in the flow rate, among other things, to allow that the second fluid impregnates within the bypass material to facilitate its removal. In some embodiments, the well may be closed for a period of time, among other purposes, to allow the bypass material to react with the second fluid and be removed. Once the bypass material has been at least partially removed, the flow rate of the second fluid can be increased to allow the fluid to penetrate into the fluid less resistant part of the formation.
    [00024] To illustrate an embodiment of the methods of the present invention, the following example of an embodiment of the invention is explained with reference to Figures 1 - 8. In no way should the following example be read as limiting or defining the integer scope of the invention.
    [00025] First we refer to Figure 1, which shows a side view
    Petition 870190078437, of 13/08/2019, p. 18/28 / 18 of the underground formation penetrated by a well bore with a column of casing tubes 10 placed inside the well bore. The well hole penetrates two zones 20 and 30 of the underground formation, where the resistance to fluid flow in zone 30 is higher than the fluid flow resistance in zone 20. Figure 2 shows the perforations 12 created in the tube coating 10. In this embodiment, the portion of the coating adjacent to zone 30 has been perforated with a higher perforation density than zone 20. Returning to Figure 3, a bypass material 14 is placed to obstruct zone 20 and the bypass fluid flowing into the borehole to other parts of the underground formation. Returning to Figure 4, a treatment fluid 16 is introduced into zone 30, despite the higher resistance of the fluid flow in zone 30, because the bypass material 14 diverts the fluid away from zone 20. Figure 5 shows the zone 30 fully treated by treatment fluid 16, which may include treatments such as fracture (i.e., introducing a fluid at a rate sufficient to create or increase one or more fractures in the underground formation), acidification, crust inhibitor treatment and / or any other underground treatment known in the art. Once zone 30 has been sufficiently treated (which can be verified by any technique known in the art, some of which are described in paragraphs below), a bypass material 18 can be placed to obstruct the now-treated zone 30 and bypass the fluids inside the well bore to other parts of the underground formation. Figure 6 illustrates the next step in this embodiment, in which a treatment fluid 40 is introduced into the well bore and the injection rate is reduced to allow the fluid to settle inside the well bore. In certain embodiments, this fluid can contact the bypass material 18 without substantially dissolving, degrading or otherwise removing the bypass material 18. However, the treatment fluid 40 can be formulated to dissolve, degrade or otherwise remove most or all of the
    Petition 870190078437, of 13/08/2019, p. 19/28 / 18 bypass material 14, as shown in Figure 7. Returning to Figure 8, if the injection rate of treatment fluid 40 is increased, treatment fluid 40 is introduced into zone 20 (in certain forms of embodiment, a fluid other than the treatment fluid 40 can be introduced on this occasion). As shown, treatment fluid 40 is diverted away from zone 30 by deflection material 18 and zone 20 is then treated (e.g., fractured, acidified, etc.) by treatment fluid 40.
    [00026] In certain embodiments, the methods of the present invention may optionally comprise introducing one or more spacer fluids or after any of the other steps of the methods of the present invention, among other purposes, to isolate different fluids used to treat the formation in different occasions. These spacer fluids can comprise any fluid known in the art, such as aqueous fluids (eg, fresh water, salt water, brines etc.), non-aqueous fluids (eg, mineral oils, synthetic oils, esters etc.) .), hydrocarbon-based fluids (eg, kerosene, xylene, toluene, diesel, oils etc.), foamed fluids (eg, a liquid comprising a gas), gels, emulsions, gases and the like. These optional spacer fluids may comprise one or more of any additional additives known in the art, as long as such additives do not interfere with other components of the fluid or other elements present during use.
    [00027] In certain embodiments, the methods of the present invention may optionally comprise monitoring the flow of one or more fluids (e.g., the first and / or second fluids) in at least a part of the underground formation during all or part of a method of the present invention, for example, to ensure that the most flow-resistant parts of the underground formation have been treated before a bypass material is removed, to determine the presence or absence of a first or second deviation in training, and / or determining whether a
    Petition 870190078437, of 8/13/2019, p. 20/28 / 18 first and / or second bypass material in the formation and / or to determine whether a first and / or second bypass material actually bypasses fluids introduced into the underground formation. This can be accomplished by any technique or combination of techniques known in the art. In certain embodiments, this can be accomplished by monitoring the pressure of the fluid at the surface of a well bore penetrating the borehole, where fluids are introduced. For example, if the fluid pressure at the surface increases, this may indicate that the fluid is being diverted to a more fluid-resistant part of the underground formation. These techniques may include various computerized fluid recording and / or fluid tracking techniques known in the art, which are capable of monitoring fluid flow. Examples of commercially available services involving surface fluid pressure measurement that may be suitable for use in the methods of the present invention include those available under the trade name EZ-GAUGE TM from Halliburton Energy Services of Duncan, Oklahoma.
    [00028] In certain embodiments, the monitoring of the flow of one or more fluids in at least part of the underground formation can be performed, in part, using a distributed temperature measurement technique (DTS). These techniques can involve a number of steps. Generally, a temperature measurement device (eg, thermocouples, RTDs or fiber optic cables) can be placed in a well hole by penetrating a part of the underground formation, either permanently or retrievably, to record temperature data in the formation and / or in the well bore. In certain applications, a fiber optic cable can be pre-installed in a casing tube column before the casing tube column is placed inside the well hole. In certain applications, it may be desirable to use an additional device (eg, coiled tubing) or fluid to place the fiber optic cable into the
    Petition 870190078437, of 8/13/2019, p. 21/28 / 18 well. In certain embodiments, the reference line temperature profile can be established for all or part of the underground formation and then monitor temperature changes to determine the flow of fluids in various parts of the underground formation. Various computer software packages can be used to process the temperature data and / or create a visualization based on that data. Certain DTS techniques that may be suitable for use in the methods of the present invention may include commercially available DTS services, such as those known under the trade names STIMWATCH (R) (available from Halliburton Energy Services of Duncan, Oklahoma) or SENSA TM (available from Schlumberger Technology Corporation, Sugar Land, Texas). Certain examples of DTS techniques that may be suitable for use in the methods of the present invention may also include those described in US Patent Nos. 7,055,604; 6,751,556; 7,086,484; 6,557,630; and 5,028,146, all of which are incorporated by reference. A person skilled in the art with the benefit of this description will recognize whether it is desirable to monitor the flow of one or more fluids in at least part of the underground formation, as well as techniques for doing so appropriate for a particular application of the present invention based on, inter alia , the characteristics (eg, fluid flow resistances) of the various parts of the underground formation, types of fluids present, equipment availability and other important factors.
    [00029] In certain embodiments, the methods of the present invention may optionally comprise monitoring the presence of a bypass material during all or part of a method of the present invention. This can be accomplished by any technique or combination of techniques known in the art. In certain embodiments, this can be accomplished by monitoring the temperature in a part of the underground formation and / or well, for example, to determine whether a bypass material has been degraded or dissolved before the less fluid-resistant part of the formation to be
    Petition 870190078437, of 13/08/2019, p. 22/28 / 18 treated. For example, the degradation and / or dissolution of certain bypass materials may comprise an exothermic reaction that gives off heat and thus an increase in temperature may indicate that the bypass material is being or has been removed. Where this monitoring step is performed, it can be performed using any means known in the art, including but not limited to the distributed temperature measurement techniques described in the paragraph above. In certain embodiments, the presence of a diversion material can be monitored by calculating the estimated time of its removal, for example, based on the rate of reaction of a diversion material with a fluid that is introduced into the hole below to degrade or dissolve the material or to initiate its own degradation. A person skilled in the art with the benefit of this description will recognize whether it is desirable to monitor the presence of a bypass material, as well as techniques for doing so, appropriate for a particular application of the present invention based, inter alia, on characteristics (e.g. resistance to fluid flow) from various parts of the underground formation, type of diversion material used, equipment availability and other important factors.
    [00030] Therefore, the present invention is well adapted to obtain the mentioned purposes and advantages as well as those that are inherent to them. The particular embodiments described above are illustrative only, since the present invention can be modified and practiced in different but equivalent ways evident to those skilled in the art, having the benefit of the teachings here. In addition, no limitation is intended for the construction or design details shown here, other than as described in the claims below. It is therefore evident that the particular illustrative embodiments described above can be altered or modified and all such variations are considered to be within the scope of the present invention. Although compositions and methods are described in terms of “comprising”, “containing” or “including”, several components
    Petition 870190078437, of 13/08/2019, p. 23/28 / 18 or steps, compositions and methods can also “consist essentially of” or “consist of” various components and steps. All numbers and ranges described above may vary by some amount. Whenever a numerical range with a lower limit and an upper limit is described, any number and any included range falling within the range is specifically described. In particular, each range of values (of the form, "from about aa to b" or, equivalently, "from approximately a to b", or equivalently, "from about approximately ab") described here is to be understood to expose each number and range covered within the broadest range of values. Also, the terms of the claims have their clear and common meaning, unless otherwise explicitly and clearly defined by the patented. In addition, the indefinite articles "one" or "one", as used in the claims, are defined here as meaning one or more than one of the element it introduces. If there is any conflict in the uses of a word or term in this report and one or more patents or other documents that may be incorporated herein by reference, definitions that are consistent with this report must be adopted.
    权利要求:
    Claims (14)
    [1]
    1. Method of placing and diverting fluid in underground formations, comprising:
    introducing a bypass material (14) into an underground formation penetrated by a well bore, to reduce or prevent the flow of fluid within a first part (20) of the underground formation;
    introducing a part of a first fluid (16) into a second part (30) of the underground formation having a greater resistance to fluid flow than the first part (20) of the underground formation; and, allowing the bypass material (14) to be removed from the underground formation after at least part of the first fluid (16) has been introduced into the second part (30) of the underground formation, characterized by the fact that it further comprises:
    introducing a part of a second fluid (40) into the first part (20) of the underground formation.
    [2]
    2. Method according to claim 1, characterized in that it further comprises the step of introducing a second bypass material (18) into the underground formation to reduce or prevent the flow of fluid into the second part (30) of the formation underground after at least a part of the first fluid (16) has been introduced into the second part (30) of the underground formation.
    [3]
    Method according to claim 2, characterized in that the second deflection material (18) is not degradable, dissolvable or otherwise removable by the second fluid (40).
    [4]
    Method according to any one of claims 1 to 3, characterized in that it further comprises the step of monitoring the flow of the first fluid (16) in the second part (30) of the underground formation.
    [5]
    5. Method according to claim 4, characterized by the fact that monitoring the flow of the first fluid (16) in the second part
    Petition 870190078683, of 14/08/2019, p. 5/7
    2/3 (30) of the underground formation comprises using a distributed temperature sensor apparatus.
    [6]
    6. Method according to claim 4, characterized by the fact that monitoring the flow of the first fluid (16) in the second part (30) of the underground formation comprises monitoring the pressure of the fluid on the surface of a well hole penetrating the formation underground.
    [7]
    Method according to any one of claims 1 to 6, characterized by the fact that it also comprises the step of monitoring the presence of the diversion material in the underground formation.
    [8]
    Method according to any one of claims 1 to 7, characterized in that one or more columns of casing tubes (10) are present in the well bore.
    [9]
    Method according to claim 8, characterized in that one or more of the liner tube columns (10) comprise a plurality of perforations (12) in a part of the liner tube column (10) adjacent to the first and second parts (20, 30) of the underground formation.
    [10]
    Method according to claim 9, characterized in that the perforation density in the part of the liner tube column (10) adjacent to the second part (30) of the underground formation is higher than the perforation density in the part of the liner tube column (10) adjacent to the first part (20) of the underground formation.
    [11]
    Method according to any one of the preceding claims, characterized in that it further comprises introducing the part of a second fluid (40) into the first part (20) of the underground formation at a rate sufficient to create or increase one or more fractures in the first part (20) of the underground formation.
    [12]
    12. Method of placing and diverting fluid in underground formations, comprising:
    Petition 870190078683, of 14/08/2019, p. 6/7
    3/3 (a) introducing a first bypass material (14) into an underground formation penetrated by a well bore, to reduce or prevent the flow of fluid within a first part (20) of the underground formation;
    (b) determining when the first bypass material (14) reduced or prevented the flow of fluid into a first part (20) of the underground formation; and, (c) introducing a part of a first fluid (16) into a second part (30) of the underground formation having a higher resistance to fluid flow than the first part (20) of the underground formation;
    characterized by the fact of still understanding:
    (d) introducing a second bypass material (18) into an underground formation penetrated by a well hole to reduce or prevent the flow of fluid into the second part (30) of the underground formation;
    (e) introducing a part of a second fluid (40) into the first part (20) of the underground formation at a first flow rate;
    (f) allowing the first diversion material (14) to be removed from the underground formation;
    (g) determining when the first bypass material (14) has been at least partially removed from the underground formation by monitoring the temperature in that part of the underground formation; and, (h) introducing a second fluid (40) into the first part (20) of the underground formation.
    [13]
    13. Method according to claim 12, characterized by the fact that step (b) or (g) comprises the use of a distributed temperature sensor device.
    [14]
    Method according to any one of claims 1 to 13, characterized in that the first deflection material (14) comprises at least one degradable material.
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    同族专利:
    公开号 | 公开日
    WO2011027100A3|2011-06-30|
    WO2011027100A2|2011-03-10|
    RU2527988C2|2014-09-10|
    US20110048708A1|2011-03-03|
    MX2012002513A|2012-04-11|
    AU2010291050A1|2012-03-15|
    NO338442B1|2016-08-15|
    BR112012004707A2|2016-04-12|
    NO20120247A1|2012-06-01|
    AU2010291050B2|2014-11-06|
    RU2012112472A|2013-10-10|
    US8016034B2|2011-09-13|
    AR078110A1|2011-10-12|
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    法律状态:
    2019-01-08| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2019-05-21| B06A| Notification to applicant to reply to the report for non-patentability or inadequacy of the application according art. 36 industrial patent law|
    2019-11-05| B09A| Decision: intention to grant|
    2019-12-31| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 27/08/2010, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US12/551,713|US8016034B2|2009-09-01|2009-09-01|Methods of fluid placement and diversion in subterranean formations|
    PCT/GB2010/001628|WO2011027100A2|2009-09-01|2010-08-27|Improved methods of fluid placement and diversion in subterranean formations|
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