CN107480899B - Reservoir water channeling identification method and device - Google Patents
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Abstract
The invention discloses a method and a device for identifying water channeling of a reservoir, and belongs to the field of drilling engineering. The method comprises the following steps: determining the average density and the average filtration loss of a drilling fluid used by a target well, wherein the target well is a well to be subjected to well cementation; determining the density and the filtration loss of the target drilling fluid; and when the sum of the density of the target drilling fluid and a preset value is smaller than the average density and the filtration loss of the target drilling fluid is larger than the average filtration loss, determining that the reservoir layer has water channeling. According to the method, the density and the filtration loss of the target drilling fluid which stays at the position of the reservoir penetrated by the target well for at least the first preset time are detected, the density and the filtration loss are compared with the average density and the average filtration loss of the drilling fluid used by the target well, and whether the reservoir has water channeling or not is judged according to the comparison result, so that the water channeling of the reservoir is simply and conveniently identified, and the accuracy of the water channeling identification is high.
Description
Technical Field
The invention relates to the field of drilling engineering, in particular to a water channeling identification method and device for a reservoir stratum.
Background
During the development of oil and gas fields, water is often injected into the reservoir to maintain and restore the reservoir pressure in order to increase the production rate and recovery of the oil. When a reservoir is drilled during drilling, if the water pressure of injection water in the reservoir is high, the injection water in the reservoir may flow into the drilled well to cause water channeling. At this time, if cement slurry is injected into the well to perform cementing, the injected water flowing into the well from the reservoir may damage the cement slurry in the form of erosion or bypass flow during the cement slurry waiting for setting, and the cementing quality may be seriously affected. Therefore, a reservoir water channeling identification method is urgently needed to identify the reservoir drilled in the drilling process so as to take measures in advance to prevent water channeling during subsequent well cementation and ensure the well cementation quality.
Disclosure of Invention
In order to perform water channeling identification on a reservoir drilled by a well, the embodiment of the invention provides a water channeling identification method and device for the reservoir. The technical scheme is as follows:
in one aspect, a method for identifying water channeling of a reservoir is provided, the method comprising:
determining the average density and the average filtration loss of a drilling fluid used by a target well, wherein the target well is a well to be subjected to well cementation;
determining the density and the fluid loss of a target drilling fluid, wherein the target drilling fluid is a drilling fluid which is stopped at the position of a reservoir layer penetrated by a target well for at least a first preset time;
and when the sum of the density of the target drilling fluid and a preset value is smaller than the average density and the filtration loss of the target drilling fluid is larger than the average filtration loss, determining that the reservoir layer has water channeling.
Optionally, the determining the average density and average fluid loss of the drilling fluid used by the target well comprises:
injecting a drilling fluid into the target well after drilling the target well, wherein the injected drilling fluid can continuously circulate in the target well;
detecting a first density and a second density in real time, wherein the first density is the density of the drilling fluid flowing into the target well, and the second density is the density of the drilling fluid flowing out of the target well;
determining the first density or the second density as an average density of drilling fluid used by the target well and detecting a first fluid loss or a second fluid loss, the first fluid loss being a fluid loss of drilling fluid flowing into the target well and the second fluid loss being a fluid loss of drilling fluid flowing out of the target well, when the first density and the second density are the same;
determining the first fluid loss or the second fluid loss as an average fluid loss of a drilling fluid used by the target well.
Optionally, the determining the density and the fluid loss of the target drilling fluid comprises:
injecting a drilling fluid into the target well after drilling the target well, wherein the injected drilling fluid can continuously circulate in the target well;
detecting the first density and the second density in real time;
stopping injecting the drilling fluid into the target well when the first density is the same as the second density, and restarting injecting the drilling fluid into the target well at a first preset time, wherein the first preset time is at least the first preset time away from the time of stopping injecting the drilling fluid into the target well;
detecting the second density and the second fluid loss at a plurality of sampling moments between a second preset moment and a third preset moment, wherein the second preset moment is a moment when the drilling fluid at the top boundary position of the reservoir layer flows out of the target well, and the third preset moment is a moment when the drilling fluid at the bottom boundary position of the reservoir layer flows out of the target well;
determining a density and a fluid loss of the target drilling fluid based on the second density and the second fluid loss detected at the plurality of sampling instants.
Optionally, before detecting the second density and the second fluid loss at a plurality of sampling moments between the second preset moment and the third preset moment, the method further includes:
determining a first time period and a second time period, wherein the first time period is the time period required for the drilling fluid at the top boundary position of the reservoir to flow out of the target well, and the second time period is the time period required for the drilling fluid at the bottom boundary position of the reservoir to flow out of the target well;
and determining the time after the first preset time and apart from the first preset time by the first time length as the second preset time, and determining the time after the first preset time and apart from the first preset time by the second time length as the third preset time.
Optionally, the determining the density and the fluid loss of the target drilling fluid based on the second density and the second fluid loss detected at the plurality of sampling instants comprises:
acquiring a minimum density of the second densities detected at the plurality of sampling instants; obtaining the second filter loss detected at the same sampling moment as the minimum density from the second filter loss detected at the plurality of sampling moments; determining the minimum density as the density of the target drilling fluid, and determining the obtained second fluid loss as the fluid loss of the target drilling fluid; alternatively, the first and second electrodes may be,
determining an average of the second densities detected at the plurality of sampling instants; determining an average value of the second fluid loss amounts detected at the plurality of sampling time instants; determining an average of the second densities as the density of the target drilling fluid and determining an average of the second fluid losses as the fluid loss of the target drilling fluid.
In another aspect, there is provided a water channeling identifying apparatus of a reservoir, the apparatus including:
the device comprises a first determination module, a second determination module and a third determination module, wherein the first determination module is used for determining the average density and the average filtration loss of the drilling fluid used by a target well, and the target well is a well to be cemented;
a second determination module for determining a density and a fluid loss of a target drilling fluid, the target drilling fluid being a drilling fluid that is stopped at a location of a reservoir through which the target well passes for at least a first preset length of time;
and the third determination module is used for determining that the reservoir generates water channeling when the sum of the density of the target drilling fluid and a preset numerical value is less than the average density and the filtration loss of the target drilling fluid is greater than the average filtration loss.
Optionally, the first determining module is mainly configured to:
injecting a drilling fluid into the target well after drilling the target well, wherein the injected drilling fluid can continuously circulate in the target well;
detecting a first density and a second density in real time, wherein the first density is the density of the drilling fluid flowing into the target well, and the second density is the density of the drilling fluid flowing out of the target well;
determining the first density or the second density as an average density of drilling fluid used by the target well and detecting a first fluid loss or a second fluid loss, the first fluid loss being a fluid loss of drilling fluid flowing into the target well and the second fluid loss being a fluid loss of drilling fluid flowing out of the target well, when the first density and the second density are the same;
determining the first fluid loss or the second fluid loss as an average fluid loss of a drilling fluid used by the target well.
Optionally, the second determining module is mainly configured to:
injecting a drilling fluid into the target well after drilling the target well, wherein the injected drilling fluid can continuously circulate in the target well;
detecting the first density and the second density in real time;
stopping injecting the drilling fluid into the target well when the first density is the same as the second density, and restarting injecting the drilling fluid into the target well at a first preset time, wherein the first preset time is at least the first preset time away from the time of stopping injecting the drilling fluid into the target well;
detecting the second density and the second fluid loss at a plurality of sampling moments between a second preset moment and a third preset moment, wherein the second preset moment is a moment when the drilling fluid at the top boundary position of the reservoir layer flows out of the target well, and the third preset moment is a moment when the drilling fluid at the bottom boundary position of the reservoir layer flows out of the target well;
determining a density and a fluid loss of the target drilling fluid based on the second density and the second fluid loss detected at the plurality of sampling instants.
Optionally, the second determining module is further configured to:
determining a first time period and a second time period, wherein the first time period is the time period required for the drilling fluid at the top boundary position of the reservoir to flow out of the target well, and the second time period is the time period required for the drilling fluid at the bottom boundary position of the reservoir to flow out of the target well;
and determining the time after the first preset time and apart from the first preset time by the first time length as the second preset time, and determining the time after the first preset time and apart from the first preset time by the second time length as the third preset time.
Optionally, the second determining module is configured to:
acquiring a minimum density of the second densities detected at the plurality of sampling instants; obtaining a second filter loss detected at the same sampling time as the minimum density from the second filter loss detected at the plurality of sampling times; determining the minimum density as the density of the target drilling fluid, and determining the obtained second fluid loss as the fluid loss of the target drilling fluid; alternatively, the first and second electrodes may be,
determining an average of the second densities detected at the plurality of sampling instants; determining an average value of the second fluid loss amounts detected at the plurality of sampling time instants; determining an average of the second densities as the density of the target drilling fluid and determining an average of the second fluid losses as the fluid loss of the target drilling fluid.
The technical scheme provided by the embodiment of the invention has the following beneficial effects: and determining the density and the filtration loss of the target drilling fluid after determining the average density and the average filtration loss of the drilling fluid used by the target well. The target drilling fluid is the drilling fluid which stays at the position of the reservoir where the target well passes through for at least the first preset time, so when the sum of the density of the target drilling fluid and the preset value is smaller than the average density and the filtration loss of the target drilling fluid is larger than the average filtration loss, the target drilling fluid can be determined to be invaded by injected water in the reservoir, and therefore the reservoir can be determined to have water channeling, the water channeling identification process is simple and convenient, and the accuracy of water channeling identification is high.
Drawings
In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the drawings needed to be used in the description of the embodiments will be briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art to obtain other drawings based on these drawings without creative efforts.
Fig. 1 is a flowchart of a method for identifying water channeling of a reservoir according to an embodiment of the present invention;
fig. 2A is a flowchart of another method for identifying water channeling in a reservoir according to an embodiment of the present invention;
FIG. 2B is a schematic diagram of a wellbore configuration of a target well according to an embodiment of the present invention;
fig. 3 is a schematic structural diagram of a water channeling identification device for a reservoir according to an embodiment of the present invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention more apparent, embodiments of the present invention will be described in detail with reference to the accompanying drawings.
Fig. 1 is a flowchart of a method for identifying water channeling of a reservoir according to an embodiment of the present invention. Referring to fig. 1, the method includes the following steps.
Step 101: and determining the average density and the average filtration loss of the drilling fluid used by the target well, wherein the target well is a well to be subjected to well cementation.
Step 102: determining the density and the fluid loss of a target drilling fluid, wherein the target drilling fluid is a drilling fluid which is stopped at the position of a reservoir penetrated by a target well for at least a first preset time.
Step 103: and when the sum of the density of the target drilling fluid and the preset value is less than the average density and the filtration loss of the target drilling fluid is greater than the average filtration loss, determining that the reservoir stratum has water channeling.
In the embodiment of the invention, after the average density and the average filtration loss of the drilling fluid used by the target well are determined, the density and the filtration loss of the target drilling fluid are determined. The target drilling fluid is the drilling fluid which stays at the position of the reservoir where the target well passes through for at least the first preset time, so when the sum of the density of the target drilling fluid and the preset value is smaller than the average density and the filtration loss of the target drilling fluid is larger than the average filtration loss, the target drilling fluid can be determined to be invaded by injected water in the reservoir, and therefore the reservoir can be determined to have water channeling, the water channeling identification process is simple and convenient, and the accuracy of water channeling identification is high.
Optionally, determining the average density and average fluid loss of the drilling fluid used by the target well comprises:
injecting a drilling fluid into the target well after the target well is drilled, wherein the injected drilling fluid can continuously and circularly flow in the target well;
detecting a first density and a second density in real time, wherein the first density is the density of the drilling fluid flowing into the target well, and the second density is the density of the drilling fluid flowing out of the target well;
when the first density is the same as the second density, determining the first density or the second density as the average density of the drilling fluid used by the target well, and detecting a first filtration loss or a second filtration loss, wherein the first filtration loss is the filtration loss of the drilling fluid flowing into the target well, and the second filtration loss is the filtration loss of the drilling fluid flowing out of the target well;
the first fluid loss or the second fluid loss is determined as an average fluid loss of the drilling fluid used by the target well.
Optionally, determining the density and fluid loss of the target drilling fluid comprises:
injecting a drilling fluid into a target well after drilling the target well, wherein the injected drilling fluid can continuously circulate in the target well;
detecting the first density and the second density in real time;
when the first density is the same as the second density, stopping injecting the drilling fluid into the target well, and restarting injecting the drilling fluid into the target well at a first preset time, wherein the first preset time is at least a first preset time away from the time of stopping injecting the drilling fluid into the target well;
detecting a second density and a second filtration loss at a plurality of sampling moments between a second preset moment and a third preset moment, wherein the second preset moment is a moment when the drilling fluid at the top boundary position of the reservoir layer flows out of the target well, and the third preset moment is a moment when the drilling fluid at the bottom boundary position of the reservoir layer flows out of the target well;
determining a density and a fluid loss of the target drilling fluid based on the second density and the second fluid loss detected at the plurality of sampling instants.
Optionally, before detecting the second density and the second fluid loss at a plurality of sampling times between the second preset time and the third preset time, the method further includes:
determining a first time length and a second time length, wherein the first time length is the time length required for the drilling fluid at the top boundary position of the reservoir to flow out of the target well, and the second time length is the time length required for the drilling fluid at the bottom boundary position of the reservoir to flow out of the target well;
and determining the time after the first preset time and apart from the first preset time by the first time length as a second preset time, and determining the time after the first preset time and apart from the first preset time by the second time length as a third preset time.
Optionally, determining the density and the fluid loss of the target drilling fluid based on the second density and the second fluid loss detected at the plurality of sampling instants comprises:
acquiring a minimum density among the second densities detected at the plurality of sampling moments; acquiring second filter loss detected at the same sampling moment with the minimum density from the second filter loss detected at a plurality of sampling moments; determining the minimum density as the density of the target drilling fluid, and determining the obtained second filter loss as the filter loss of the target drilling fluid; alternatively, the first and second electrodes may be,
determining an average of the second densities detected at the plurality of sampling instants; determining an average value of the second fluid loss amounts detected at a plurality of sampling moments; and determining the average value of the second density as the density of the target drilling fluid, and determining the average value of the second fluid loss as the fluid loss of the target drilling fluid.
All the above optional technical solutions can be combined arbitrarily to form an optional embodiment of the present invention, which is not described in detail herein.
Fig. 2A is a flowchart of a method for identifying water channeling of a reservoir according to an embodiment of the present invention. Referring to fig. 2A, the method includes the following steps.
Step 201: and after drilling a target well, injecting drilling fluid into the target well, wherein the target well is a well to be subjected to well cementation.
After the target well is drilled, the drill bit can be placed below the bottom boundary of a reservoir layer penetrated by the target well through drilling equipment, then the drilling fluid is injected into the target well through the circulating pump, at the moment, the drilling fluid can flow into the target well from the drill rod and flow out of the target well from an annular space between the drill rod and a well wall, and therefore the drilling fluid can continuously and circularly flow in the target well.
Step 202: and detecting a first density and a second density in real time, wherein the first density is the density of the drilling fluid flowing into the target well, and the second density is the density of the drilling fluid flowing out of the target well.
In the process of continuous circulation flow of the drilling fluid in the target well, the drilling fluid flowing into the target well and the drilling fluid flowing out of the target well can be sampled in real time, of course, the drilling fluid flowing into the target well and the drilling fluid flowing out of the target well can also be sampled at intervals of a second preset time length, then, the density of the drilling fluid sample obtained through sampling can be determined, the density of the drilling fluid sample obtained through sampling from the drilling fluid flowing into the target well is used as a first density, and the density of the drilling fluid sample obtained through sampling from the drilling fluid flowing out of the target well is used as a second density.
It should be noted that the second preset time period may be preset, for example, the second preset time period may be 10 minutes, 15 minutes, 20 minutes, and so on.
When the density of the drilling fluid sample obtained by sampling is determined, the density of the drilling fluid sample can be obtained by performing density detection on the drilling fluid sample through a density detector. Of course, in practical applications, the density of the drilling fluid sample may be determined in other manners, for example, the density of the drilling fluid sample may be determined according to the following first specified formula based on the mass and the volume of the drilling fluid sample;
the first specified formula: rho-m/v
Wherein in the first specified formula, ρ is the density of the drilling fluid sample; m refers to the mass of the drilling fluid sample; v refers to the volume of the drilling fluid sample.
Step 203: and when the first density is the same as the second density, determining the first density or the second density as the average density of the drilling fluid used by the target well, detecting the first filtration loss or the second filtration loss, and determining the first filtration loss or the second filtration loss as the average filtration loss of the drilling fluid used by the target well.
The first fluid loss is a fluid loss of the drilling fluid flowing into the target well, and the second fluid loss is a fluid loss of the drilling fluid flowing out of the target well.
When the first density is the same as the second density, it indicates that the drilling fluid in the target well is relatively uniform, that is, the density of the drilling fluid at each position in the target well is the same, so that the first density or the second density detected at this time can be determined as the average density of the drilling fluid used by the target well, and the first fluid loss or the second fluid loss is detected and determined as the average fluid loss of the drilling fluid used by the target well.
For example, when the first density is detected to be 1.25 g/cc, the second density is detected to be 1.25 g/cc, and the first density is the same as the second density, the detected first density or the detected second density of 1.25 g/cc may be determined as the average density of the drilling fluid used by the target well, and the first fluid loss or the second fluid loss is detected, and if the detected first fluid loss or the detected second fluid loss is 4.7 ml, the detected first fluid loss or the detected second fluid loss of 4.7 ml may be determined as the average fluid loss of the drilling fluid used by the target well.
When the first filtration loss or the second filtration loss is detected, the drilling fluid flowing into or out of the target well can be sampled, the filtration loss of a drilling fluid sample obtained by sampling is determined, the filtration loss of the drilling fluid sample obtained by sampling from the drilling fluid flowing into the target well is used as the first filtration loss, and the filtration loss of the drilling fluid sample obtained by sampling from the drilling fluid flowing out of the target well is used as the second filtration loss.
When the filtration loss of the drilling fluid sample obtained by sampling is determined, the filtration loss of the drilling fluid sample can be detected under a preset condition to obtain the filtration loss of the drilling fluid sample. Of course, in practical applications, the fluid loss of the drilling fluid sample obtained by sampling may be determined in other manners, which is not limited in the embodiment of the present invention.
It should be noted that the preset conditions may be low temperature and low pressure conditions (e.g., 18 degrees celsius and 690 kpa), high temperature and high pressure conditions (e.g., 200 degrees celsius and 1704 kpa), and the like. When the fluid loss detection is performed under the low-temperature and low-Pressure conditions, the obtained fluid loss is low-temperature and low-Pressure fluid loss, namely API (American Petroleum Institute), and the fluid loss detection is performed under the High-temperature and High-Pressure conditions, and the obtained fluid loss is High-temperature and High-Pressure fluid loss, namely HTHP (High temperature and High Pressure) fluid loss.
It should be noted that, in the embodiment of the present invention, the average density and the average fluid loss of the drilling fluid used by the target well may be determined through the above step 201 and step 203, but, in practical applications, the average density and the average fluid loss of the drilling fluid used by the target well may also be determined in other manners, for example, when the setting instruction is detected, the density carried in the setting instruction is determined as the average density of the drilling fluid used by the target well, and the fluid loss carried in the setting instruction is determined as the average fluid loss of the drilling fluid used by the target well.
In addition, the setting instruction is used for setting the average density and the average filtration loss of the drilling fluid used by the target well, the setting instruction can be triggered by a technician, the technician can trigger the setting instruction through specified operation, and the specified operation can be single-click operation, double-click operation and the like.
It should be noted that in the embodiment of the present invention, when the first density is the same as the second density, not only the average density and the average fluid loss of the drilling fluid used by the target well may be determined in step 203, but also the density and the fluid loss of the target drilling fluid may be determined by continuing to step 204 and 206 as follows, and the target drilling fluid is the drilling fluid that is stopped at the location of the reservoir through which the target well passes for at least the first preset time period.
Step 204: and stopping injecting the drilling fluid into the target well, and restarting injecting the drilling fluid into the target well at the first preset moment.
When the first density is the same as the second density, the drilling fluid in the drilled well is uniform, the drilling fluid injection into the target well can be stopped at the moment, the drilling fluid in the target well is ensured to be in a static state, and the injected water in the reservoir can fully invade the drilling fluid at the position of the reservoir under the condition that the reservoir penetrated by the target well has water channeling. And then, restarting injecting the drilling fluid into the target well at the first preset moment, so that the target drilling fluid which is stopped at the position of the reservoir for at least a first preset time can flow out of the target well, and performing subsequent detection on the density and the fluid loss.
It should be noted that the first preset time is at least one preset time away from the time of stopping injecting the drilling fluid into the target well. The first preset time period may be preset, and the first preset time period should be able to ensure that when water channeling occurs in the reservoir, the injected water in the reservoir may fully invade into the drilling fluid at the location of the reservoir, for example, the first preset time period may be 6 hours, 7 hours, 8 hours, and the like.
For example, the first predetermined time may be determined based on the time at which the drilling fluid injection into the target well is actually stopped in step 204, e.g., a time at least a first predetermined time period after the time at which the drilling fluid injection into the target well is actually stopped may be determined as the first predetermined time, e.g., a time at which the drilling fluid circulation in the drilling well is actually stopped in step 204 is 9:00 am and the first predetermined time period is 7 hours, and a time 4:00 pm after 9:00 am and 7 hours from 9:00 am may be determined as the first predetermined time.
Of course, the first preset time may be preset before step 204, and the technician may preset the time for stopping injecting the drilling fluid into the target well, and set the time after the preset time and at least a first preset time from the preset time as the first preset time, for example, the technician may preset the time for stopping injecting the drilling fluid into the target well to be 9:45 a.m. and the first preset time to be 7 hours, and may determine 4:45 pm as the first preset time after 9:45 a.m. and 7 hours from 9:45 a.m.
Step 205: and detecting the second density and the second filter loss at a plurality of sampling moments between the second preset moment and the third preset moment.
It should be noted that the second preset time is a time when the drilling fluid at the top boundary position of the reservoir layer flows out of the target well, and the third preset time is a time when the drilling fluid at the bottom boundary position of the reservoir layer flows out of the target well.
In addition, the plurality of sampling moments may be preset, and for example, the plurality of sampling moments may be a plurality of sampling moments obtained by dividing a time period between the second preset moment and the third preset moment by a third preset time period, and of course, the plurality of sampling moments may also be preset in other manners, which is not limited in this embodiment of the present invention. The third preset time period may be preset, for example, the third preset time period may be 30 seconds, 40 seconds, and the like.
Further, before step 205, a second preset time and a third preset time may also be determined. Specifically, a first duration and a second duration may be determined, a time after the first preset time and apart from the first preset time by the first duration is determined as a second preset time, and a time after the first preset time and apart from the first preset time by the second duration is determined as a third preset time.
It should be noted that the first time period is a time period required for the drilling fluid at the top boundary position of the reservoir to flow out of the target well, and the second time period is a time period required for the drilling fluid at the bottom boundary position of the reservoir to flow out of the target well.
In addition, when the first preset time is preset before step 204, the second preset time and the third preset time may be determined based on the first preset time after the first preset time is obtained before step 204. When the first preset time is determined to be obtained in step 204, the second preset time and the third preset time may be determined to be obtained based on the first preset time after the first preset time is obtained in step 204.
Wherein, when the first time length and the second time length are determined, the first time length or the second time length can be determined according to a second specified formula based on the inner diameter of the casing, the height of the casing, the borehole diameter of the target well, the outer diameter of the drill pipe, the depth of the reservoir boundary and the displacement of the drilling fluid;
the second specified formula:
wherein, in the second specified formula, T is the time length required for the drilling fluid at the boundary position of the reservoir to flow out of the target well, and D1Is the inner diameter of the casing, H1Is the height of the sleeve, D2The diameter of a borehole of a target well, d the outer diameter of the drill rod, H the depth of the reservoir boundary, Q the displacement of the drilling fluid, and pi the circumferential rate which is a constant.
It should be noted that, when the boundary of the reservoir is the top boundary of the reservoir, the first time length required for the drilling fluid at the top boundary position of the reservoir to flow out of the target well is determined according to the second specified formula, and when the boundary of the reservoir is the bottom boundary of the reservoir, the second time length required for the drilling fluid at the bottom boundary position of the reservoir to flow out of the target well is determined according to the second specified formula.
For example, as shown in fig. 2B, the body structure of the target well is that the inner diameter of the casing of the target well is 226.6 mm, the height of the casing is 500 m, the outer diameter of the drill pipe is 127 mm, the borehole diameter of the target well is 215.9 mm, the depth of the top boundary of the reservoir is 1100 m, the depth of the bottom boundary of the reservoir is 1500 m, and the displacement of the drilling fluid is 1.8 m/min, it can be determined according to the second specified formula that the first time period required for the drilling fluid at the top boundary position of the reservoir to flow out of the target well is about 15 min, and the second time period required for the drilling fluid at the bottom boundary position of the reservoir to flow out of the target well is about 21 min.
Step 206: determining a density and a fluid loss of the target drilling fluid based on the second density and the second fluid loss detected at the plurality of sampling instants.
Specifically, step 206 may be implemented in two ways. Of course, in practical applications, the step 206 may also be implemented in other ways, which is not limited by the embodiment of the present invention.
The first mode is as follows: acquiring a minimum density among the second densities detected at the plurality of sampling moments; obtaining a second filter loss detected at the same sampling moment with the minimum density from the second filter losses detected at the plurality of sampling moments; and determining the minimum density as the density of the target drilling fluid, and determining the obtained second fluid loss as the fluid loss of the target drilling fluid.
For example, the plurality of sampling moments between the second preset moment and the third preset moment are the first sampling moment, the second sampling moment, the third sampling moment and the fourth sampling moment, and the second density detected at the first sampling moment is 1.19 g/cc, the second filtrate loss is 5.2 ml, the second density detected at the second sampling moment is 1.17 g/cc, the second filtrate loss is 5.4 ml, the second density detected at the third sampling moment is 1.16 g/cc, the second filtrate loss is 5.6 ml, the second density detected at the fourth sampling moment is 1.18 g/cc, the second filtrate loss is 5.3 ml, a minimum density of 1.16 grams/cubic centimeter of the second densities detected at the plurality of sampling instants may be determined as the density of the target drilling fluid, and a second loss of 5.6 ml detected at the same sampling time as the minimum density is determined as the loss of the target drilling fluid.
The second mode is as follows: determining an average of the second densities detected at the plurality of sampling instants; and determining an average value of the second fluid loss amounts detected at the plurality of sampling moments; and determining the average value of the determined second densities as the density of the target drilling fluid, and determining the average value of the determined second fluid loss as the fluid loss of the target drilling fluid.
For example, the plurality of sampling moments between the second preset moment and the third preset moment are the first sampling moment, the second sampling moment, the third sampling moment and the fourth sampling moment, and the second density detected at the first sampling moment is 1.19 g/cc, the second filtrate loss is 5.2 ml, the second density detected at the second sampling moment is 1.17 g/cc, the second filtrate loss is 5.4 ml, the second density detected at the third sampling moment is 1.16 g/cc, the second filtrate loss is 5.6 ml, the second density detected at the fourth sampling moment is 1.18 g/cc, the second filtrate loss is 5.3 ml, the average of the second densities detected at the plurality of sampling instants of 1.175 grams per cubic centimeter may be determined as the density of the target drilling fluid, and determining the average value 5.375 milliliters of the second fluid loss detected at the plurality of sampling moments as the fluid loss of the target drilling fluid.
It should be noted that, in the embodiment of the present invention, the density and the fluid loss of the target drilling fluid may be determined through the step 204 and the step 206, and of course, in practical applications, the density and the fluid loss of the target drilling fluid may also be determined in other manners, which is not limited in the embodiment of the present invention.
Step 207: and when the sum of the density of the target drilling fluid and a preset value is less than the average density and the filtration loss of the target drilling fluid is greater than the average filtration loss, determining that the reservoir stratum has water channeling.
The preset value can be preset, and the preset value can be set according to actual application requirements, for example, when the density of the target drilling fluid is the minimum density of the second densities detected at the multiple sampling moments, the preset value can be 0.018 g/cc, 0.020 g/cc, or 0.022 g/cc, etc.; when the density of the target drilling fluid is an average of the second densities detected at the plurality of sampling instants, the preset value may be 0.006 g/cc, 0.008 g/cc, or 0.010 g/cc, etc.
When the sum of the density of the target drilling fluid and the preset value is smaller than the average density of the drilling fluid used by the target well, the density of the target drilling fluid is far smaller than the average density of the drilling fluid used by the target well, on this basis, the filtration loss of the target drilling fluid is larger than the average filtration loss of the drilling fluid used by the target well, and the content of moisture in the target drilling fluid is far larger than the average content of moisture in the drilling fluid used by the target well, the target drilling fluid can be determined to be invaded by the injected water in the reservoir, namely, the reservoir has water channeling.
Continuing with the above example, at a predetermined value of 0.020 g/cc, the density of the target drilling fluid is 1.16 g/cc, the average density of the drilling fluid used in the target well is 1.20 g/cc, the fluid loss of the target drilling fluid is 5.6 ml, and the average fluid loss of the drilling fluid used in the target well is 5 ml. The sum of the preset value and the density of the target drilling fluid is 1.18 g/cubic centimeter, and the reservoir can be determined to have water channeling because the 1.18 g/cubic centimeter is less than 1.20 g/cubic centimeter and the filtration loss of the target drilling fluid is more than 5 ml and 5.6 ml.
Further, after determining that water breakthrough has occurred in the reservoir, the density of the drilling fluid may be increased appropriately, and steps 201-207 may be repeated until it is determined that water breakthrough has not occurred in the reservoir. When the reservoir is determined not to generate water channeling, an annular slurry column structure during well cementation can be designed based on the average density of the drilling fluid used by the target well and the depth of the bottom boundary of the reservoir at the moment so as to prevent the water channeling during well cementation.
For example, the depth of the bottom boundary of the reservoir is 1500 meters, when the reservoir is not subjected to water channeling, the average density of the drilling fluid used by the target well is 1.23 g/cc, and then the bottom boundary pressure of the reservoir is determined to be 18.08 mpa based on the average density of the drilling fluid used by the target well being 1.23 g/cc and the depth of the bottom boundary of the reservoir being 1500 meters, so that when the pressure of an annular slurry column used for subsequent well cementation is greater than the bottom boundary pressure of the reservoir being 18.08 mpa, the reservoir is not subjected to water channeling. Thus, the annular slurry column structure at the time of cementing may be designed on this basis, for example, it may be, from top to bottom in the target well: 800 meters of drilling fluid with the density of 1.23 g/cubic centimeter, 300 meters of retarding cement slurry with the density of 1.90 g/cubic centimeter and 400 meters of quick-setting cement slurry with the density of 1.90 g/cubic centimeter, wherein during the quick-setting cement slurry waiting setting period, the density of the quick-setting cement slurry can be calculated according to 1.03 g/cubic centimeter, and the pressure of the annular slurry column is 19.27 MPa and is greater than the bottom pressure of a reservoir stratum, so that the reservoir stratum can not generate water channeling and can not influence the well cementation of a target well.
In the embodiment of the invention, after the target well is drilled, in order to determine whether water channeling occurs in a reservoir layer penetrated by the target well, drilling fluid can be injected into the target well, the drilling fluid can be ensured to continuously and circularly flow in the target well, the density of the drilling fluid flowing out of the target well and the density of the drilling fluid flowing into the target well are detected in real time, and when the density of the drilling fluid flowing out of the target well and the density of the drilling fluid flowing into the target well are the same, the density and the filtration loss of the drilling fluid flowing out of or into the target well are respectively determined as the average density and the average filtration loss of the drilling fluid used by the target well. And then stopping injecting the drilling fluid into the target well, restarting injecting the drilling fluid into the target well at the first preset time, detecting the density and the filtration loss of the drilling fluid flowing out of the target well at a plurality of sampling times between the second preset time and the third preset time, and determining the density and the filtration loss of the target drilling fluid according to the density and the filtration loss. Because the target drilling fluid is the drilling fluid which is stopped at the position of the reservoir for at least the first preset time, when the sum of the density of the target drilling fluid and the preset value is smaller than the average density of the drilling fluid used by the target well and the filtration loss of the target drilling fluid is larger than the average filtration loss of the drilling fluid used by the target well, the reservoir can be determined to have water channeling, the water channeling identification process is simple and convenient, and the accuracy of water channeling identification is high.
Fig. 3 is a schematic structural diagram of a water channeling identification device for a reservoir according to an embodiment of the present invention. Referring to fig. 3, the apparatus includes:
the first determining module 301 is configured to determine an average density and an average filter loss of a drilling fluid used by a target well, where the target well is a well to be cemented;
a second determination module 302 for determining a density and a fluid loss of a target drilling fluid, the target drilling fluid being a drilling fluid that is stopped at a location of a reservoir through which a target well passes for at least a first preset time period;
and a third determining module 303, configured to determine that water channeling occurs in the reservoir when the sum of the density of the target drilling fluid and the preset value is smaller than the average density and the fluid loss of the target drilling fluid is greater than the average fluid loss.
Optionally, the first determining module 301 is mainly configured to:
injecting a drilling fluid into the target well after the target well is drilled, wherein the injected drilling fluid can continuously and circularly flow in the target well;
detecting a first density and a second density in real time, wherein the first density is the density of the drilling fluid flowing into the target well, and the second density is the density of the drilling fluid flowing out of the target well;
when the first density is the same as the second density, determining the first density or the second density as the average density of the drilling fluid used by the target well, and detecting a first filtration loss or a second filtration loss, wherein the first filtration loss is the filtration loss of the drilling fluid flowing into the target well, and the second filtration loss is the filtration loss of the drilling fluid flowing out of the target well;
the first fluid loss or the second fluid loss is determined as an average fluid loss of the drilling fluid used by the target well.
Optionally, the second determining module 302 is mainly configured to:
injecting a drilling fluid into the target well after the target well is drilled, wherein the injected drilling fluid can continuously and circularly flow in the target well;
detecting the first density and the second density in real time;
when the first density is the same as the second density, stopping injecting the drilling fluid into the target well, and restarting injecting the drilling fluid into the target well at a first preset time, wherein the first preset time is at least a first preset time away from the time of stopping injecting the drilling fluid into the target well;
detecting a second density and a second filtration loss at a plurality of sampling moments between a second preset moment and a third preset moment, wherein the second preset moment is a moment when the drilling fluid at the top boundary position of the reservoir layer flows out of the target well, and the third preset moment is a moment when the drilling fluid at the bottom boundary position of the reservoir layer flows out of the target well;
determining a density and a fluid loss of the target drilling fluid based on the second density and the second fluid loss detected at the plurality of sampling instants.
Optionally, the second determining module 302 is further configured to:
determining a first time length and a second time length, wherein the first time length is the time length required for the drilling fluid at the top boundary position of the reservoir to flow out of the target well, and the second time length is the time length required for the drilling fluid at the bottom boundary position of the reservoir to flow out of the target well;
and determining the time after the first preset time and apart from the first preset time by the first time length as a second preset time, and determining the time after the first preset time and apart from the first preset time by the second time length as a third preset time.
Optionally, the second determining module 302 is configured to:
acquiring a minimum density among the second densities detected at the plurality of sampling moments; acquiring second filter loss detected at the same sampling moment with the minimum density from the second filter loss detected at the plurality of sampling moments; determining the minimum density as the density of the target drilling fluid, and determining the obtained second filter loss as the filter loss of the target drilling fluid; alternatively, the first and second electrodes may be,
determining an average of the second densities detected at the plurality of sampling instants; determining an average value of the second fluid loss amounts detected at the plurality of sampling moments; and determining the average value of the second density as the density of the target drilling fluid, and determining the average value of the second fluid loss as the fluid loss of the target drilling fluid.
In the embodiment of the invention, after the average density and the average filter loss of the drilling fluid used by the target well are determined, the density and the filter loss of the target drilling fluid are determined. The target drilling fluid is the drilling fluid which stays at the position of the reservoir where the target well passes through for at least the first preset time, so when the sum of the density of the target drilling fluid and the preset value is smaller than the average density and the filtration loss of the target drilling fluid is larger than the average filtration loss, the target drilling fluid can be determined to be invaded by injected water in the reservoir, and therefore the reservoir can be determined to have water channeling, the water channeling identification process is simple and convenient, and the accuracy of water channeling identification is high.
It should be noted that: when the water channeling identification device for the reservoir provided by the above embodiment identifies the water channeling of the reservoir, only the division of the function modules is illustrated, and in practical application, the function distribution can be completed by different function modules according to needs, that is, the internal structure of the device is divided into different function modules, so as to complete all or part of the functions described above. In addition, the water channeling identification device for the reservoir and the water channeling identification method for the reservoir provided by the embodiment belong to the same concept, and specific implementation processes are detailed in the method embodiment and are not described again.
It will be understood by those skilled in the art that all or part of the steps for implementing the above embodiments may be implemented by hardware, or may be implemented by a program instructing relevant hardware, where the program may be stored in a computer-readable storage medium, and the above-mentioned storage medium may be a read-only memory, a magnetic disk or an optical disk, etc.
The above description is only for the purpose of illustrating the preferred embodiments of the present invention and is not to be construed as limiting the invention, and any modifications, equivalents, improvements and the like that fall within the spirit and principle of the present invention are intended to be included therein.
Claims (6)
1. A method of identifying water channeling from a reservoir, the method comprising:
determining the average density and the average filtration loss of a drilling fluid used by a target well, wherein the target well is a well to be subjected to well cementation;
determining the density and the fluid loss of a target drilling fluid, wherein the target drilling fluid is a drilling fluid which is stopped at the position of a reservoir layer penetrated by a target well for at least a first preset time;
when the sum of the density of the target drilling fluid and a preset value is smaller than the average density and the filtration loss of the target drilling fluid is larger than the average filtration loss, determining that water channeling occurs in the reservoir;
the determining the average density and the average filter loss of the drilling fluid used by the target well comprises the following steps:
injecting a drilling fluid into the target well after drilling the target well, wherein the injected drilling fluid can continuously circulate in the target well;
detecting a first density and a second density in real time, wherein the first density is the density of the drilling fluid flowing into the target well, and the second density is the density of the drilling fluid flowing out of the target well;
determining the first density or the second density as an average density of drilling fluid used by the target well and detecting a first fluid loss or a second fluid loss, the first fluid loss being a fluid loss of drilling fluid flowing into the target well and the second fluid loss being a fluid loss of drilling fluid flowing out of the target well, when the first density and the second density are the same;
determining the first fluid loss or the second fluid loss as an average fluid loss of a drilling fluid used by the target well;
the determining the density and the fluid loss of the target drilling fluid comprises the following steps:
injecting a drilling fluid into the target well after drilling the target well, wherein the injected drilling fluid can continuously circulate in the target well;
detecting the first density and the second density in real time;
stopping injecting the drilling fluid into the target well when the first density is the same as the second density, and restarting injecting the drilling fluid into the target well at a first preset time, wherein the first preset time is at least the first preset time away from the time of stopping injecting the drilling fluid into the target well;
detecting the second density and the second fluid loss at a plurality of sampling moments between a second preset moment and a third preset moment, wherein the second preset moment is a moment when the drilling fluid at the top boundary position of the reservoir layer flows out of the target well, and the third preset moment is a moment when the drilling fluid at the bottom boundary position of the reservoir layer flows out of the target well;
determining a density and a fluid loss of the target drilling fluid based on the second density and the second fluid loss detected at the plurality of sampling instants.
2. The method of claim 1, wherein prior to detecting the second density and second fluid loss at a plurality of sampling instants between a second preset instant and a third preset instant, further comprising:
determining a first time period and a second time period, wherein the first time period is the time period required for the drilling fluid at the top boundary position of the reservoir to flow out of the target well, and the second time period is the time period required for the drilling fluid at the bottom boundary position of the reservoir to flow out of the target well;
and determining the time after the first preset time and apart from the first preset time by the first time length as the second preset time, and determining the time after the first preset time and apart from the first preset time by the second time length as the third preset time.
3. The method of claim 1 or 2, wherein the determining the density and the fluid loss of the target drilling fluid based on the second density and the second fluid loss detected at the plurality of sampling instants comprises:
acquiring a minimum density of the second densities detected at the plurality of sampling instants; obtaining the second filter loss detected at the same sampling moment as the minimum density from the second filter loss detected at the plurality of sampling moments; determining the minimum density as the density of the target drilling fluid, and determining the obtained second fluid loss as the fluid loss of the target drilling fluid; alternatively, the first and second electrodes may be,
determining an average of the second densities detected at the plurality of sampling instants; determining an average value of the second fluid loss amounts detected at the plurality of sampling time instants; determining an average of the second densities as the density of the target drilling fluid and determining an average of the second fluid losses as the fluid loss of the target drilling fluid.
4. A water channeling identification device for a reservoir, the device comprising:
the device comprises a first determination module, a second determination module and a third determination module, wherein the first determination module is used for determining the average density and the average filtration loss of the drilling fluid used by a target well, and the target well is a well to be cemented;
a second determination module for determining a density and a fluid loss of a target drilling fluid, the target drilling fluid being a drilling fluid that is stopped at a location of a reservoir through which the target well passes for at least a first preset length of time;
the third determination module is used for determining that water channeling occurs in the reservoir when the sum of the density of the target drilling fluid and a preset numerical value is smaller than the average density and the filtration loss of the target drilling fluid is larger than the average filtration loss;
the first determining module is mainly used for:
injecting a drilling fluid into the target well after drilling the target well, wherein the injected drilling fluid can continuously circulate in the target well;
detecting a first density and a second density in real time, wherein the first density is the density of the drilling fluid flowing into the target well, and the second density is the density of the drilling fluid flowing out of the target well;
determining the first density or the second density as an average density of drilling fluid used by the target well and detecting a first fluid loss or a second fluid loss, the first fluid loss being a fluid loss of drilling fluid flowing into the target well and the second fluid loss being a fluid loss of drilling fluid flowing out of the target well, when the first density and the second density are the same;
determining the first fluid loss or the second fluid loss as an average fluid loss of a drilling fluid used by the target well;
the second determining module is mainly configured to:
injecting a drilling fluid into the target well after drilling the target well, wherein the injected drilling fluid can continuously circulate in the target well;
detecting the first density and the second density in real time;
stopping injecting the drilling fluid into the target well when the first density is the same as the second density, and restarting injecting the drilling fluid into the target well at a first preset time, wherein the first preset time is at least the first preset time away from the time of stopping injecting the drilling fluid into the target well;
detecting the second density and the second fluid loss at a plurality of sampling moments between a second preset moment and a third preset moment, wherein the second preset moment is a moment when the drilling fluid at the top boundary position of the reservoir layer flows out of the target well, and the third preset moment is a moment when the drilling fluid at the bottom boundary position of the reservoir layer flows out of the target well;
determining a density and a fluid loss of the target drilling fluid based on the second density and the second fluid loss detected at the plurality of sampling instants.
5. The apparatus of claim 4, wherein the second determination module is further to:
determining a first time period and a second time period, wherein the first time period is the time period required for the drilling fluid at the top boundary position of the reservoir to flow out of the target well, and the second time period is the time period required for the drilling fluid at the bottom boundary position of the reservoir to flow out of the target well;
and determining the time after the first preset time and apart from the first preset time by the first time length as the second preset time, and determining the time after the first preset time and apart from the first preset time by the second time length as the third preset time.
6. The apparatus of claim 4 or 5, wherein the second determining module is to:
acquiring a minimum density of the second densities detected at the plurality of sampling instants; obtaining a second filter loss detected at the same sampling time as the minimum density from the second filter loss detected at the plurality of sampling times; determining the minimum density as the density of the target drilling fluid, and determining the obtained second fluid loss as the fluid loss of the target drilling fluid; alternatively, the first and second electrodes may be,
determining an average of the second densities detected at the plurality of sampling instants; determining an average value of the second fluid loss amounts detected at the plurality of sampling time instants; determining an average of the second densities as the density of the target drilling fluid and determining an average of the second fluid losses as the fluid loss of the target drilling fluid.
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