CN107842361B - Method for measuring original formation temperature, empty wellbore static temperature, annulus static temperature and annulus dynamic temperature - Google Patents
Method for measuring original formation temperature, empty wellbore static temperature, annulus static temperature and annulus dynamic temperature Download PDFInfo
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Abstract
The invention relates to the field of petroleum drilling, in particular to a method for measuring the original formation temperature, the static temperature of an empty well casing, the static temperature of an annulus and the dynamic temperature of the annulus. A method of measuring virgin formation temperature, comprising: after the well is opened and the fluid of the well bore and the stratum reach thermodynamic equilibrium, a cable type temperature measuring device is put into the well, and the static temperature distribution of the open well bore is obtained; obtaining the static temperature distribution of the second open-air well cylinder; obtaining a three-hollowed-out shaft static temperature distribution; and fitting the static temperature distribution of the first open hole shaft, the static temperature distribution of the second open hole shaft and the static temperature distribution data of the third open hole shaft to obtain the original formation temperature distribution of the whole well section. The original formation temperature, the dynamic temperature change and the static temperature in the shaft, the temperature of fluid (or drilling fluid) in the shaft and the temperature increasing quantity of the fluid can be deduced through the test results and calculation, and the dynamic change characteristics of the formation and shaft temperatures under different working conditions in the well are predicted.
Description
Technical Field
The invention relates to the field of petroleum drilling, in particular to a method for measuring the original formation temperature, the static temperature of an empty well casing, the static temperature of an annulus and the dynamic temperature of the annulus.
Background
During the process of developing and utilizing geothermal resources, underground water resources and underground oil and gas resources and carrying out geoscience exploration, human beings need to drill a shaft with the depth of thousands of meters to tens of thousands of meters on the crust of the earth. But during drilling the formation temperature will gradually increase as the well depth increases. The increase of the formation temperature has great influence on the drilling and rock breaking tools, the thermal stability of the drill bit and the temperature resistance of the drilling fluid. Therefore, it is often necessary to know the temperature of the original formation and the temperature of the wellbore during drilling along with the depth to ensure safe and efficient drilling.
The current method of obtaining virgin formation temperature is: and (3) putting a temperature measuring instrument into the drilled shaft for direct measurement, namely obtaining the temperature of the drilling fluid at a single time isolated depth point under the condition that the circulation of the shaft fluid is stopped by the temperature measuring instrument. On one hand, the temperature field of the near wellbore zone is disturbed because the fluid continuously brings the heat of the near wellbore wall formation to the ground through long-time circulation in the drilling process (Keller, 1973; Epinesa-Paredesa, 2001, 2009); on the other hand, the presence of highly thermally conductive drill strings and casing in the wellbore after drilling and completion of drilling has significantly changed the heat exchange efficiency between the wellbore and the formation (Yang,2013,2015). Thus, the current measurement methods have measured wellbore temperature distributions that differ from the original formation temperature distribution.
Therefore, the invention provides a method for acquiring the temperature distribution of the original formation of the deep well and the temperature distribution of the shaft.
Disclosure of Invention
The invention aims to provide a method for measuring the temperature of an original formation, the static temperature of an empty well bore, the static temperature of an annulus and the dynamic temperature of the annulus, and aims to solve the problem that the temperature distribution of the well bore measured by the conventional measuring method is different from the temperature distribution of the original formation.
The invention provides a technical scheme that:
a method of measuring virgin formation temperature, comprising:
after the well is opened and the thermodynamic equilibrium between the fluid in the well bore and the stratum is reached, a cable temperature measuring device is put into the well, and the relation between the temperature detected by the cable temperature measuring device and the well depth is the static temperature distribution of the open well bore;
performing second-cut drilling, and after the fluid of the well bore and the stratum reach thermodynamic equilibrium, putting a cable type temperature measuring device into the second-cut well to obtain the static temperature distribution of the second-cut hollow well bore;
performing three-opening well drilling, and when the fluid of the shaft and the stratum reach thermodynamic equilibrium, putting a cable type temperature measuring device into the three-opening well to obtain the static temperature distribution of the three-opening shaft;
and fitting the static temperature distribution of the first open hole shaft, the static temperature distribution of the second open hole shaft and the static temperature distribution data of the third open hole shaft to obtain the original formation temperature distribution of the whole well section.
The invention also provides a technical scheme that:
a method of measuring static temperature of an empty wellbore, comprising: and after the well drilling is finished, when the fluid in the well bore and the stratum reach thermodynamic equilibrium, a cable type temperature measuring device is put into the well to obtain the static temperature distribution of the empty well bore.
A method for measuring the static temperature of an annular space comprises the following steps: after drilling, after the fluid in the shaft and the stratum reach thermodynamic equilibrium, arranging the temperature measuring device in a drill column, putting the drill column into the well, standing for 4-6 hours, taking out the drill column, and taking the relation between the temperature recorded by the temperature measuring device and the well depth as the annular static temperature.
A method for measuring dynamic temperature of annular space comprises the following steps: installing a temperature measuring device on a drill string, wherein before the drill string drills: t is t0At all times, the temperature measuring device is at the well depth H0At position, temperature T0(ii) a Drilling is carried out, t1At the moment, the drill string drills to the well depth H1At a temperature of T1(ii) a At t0-t1And (3) recording time and well depth (T-H) relation data by using time period and logging data, recording time and annulus temperature (T-T) data by using a temperature measuring device, and synthesizing the data on the two planes to obtain a time-well depth-temperature (T-H-T) space line.
The method for measuring the original formation temperature, the static temperature of the empty well casing, the static temperature of the annulus and the dynamic temperature of the annulus provided by the embodiment of the invention has the beneficial effects that:
the invention provides a method for acquiring the original formation temperature and the annulus static temperature of deep well drilling; according to the invention, the dynamic distribution characteristics of the annular temperature at different time points can be obtained by applying an inversion method by adopting the annular temperature data measured by a plurality of temperature measuring short circuits at different times and different depths. According to the annular temperature data at different time and different depths, the dynamic distribution rule of the annular temperature at a certain depth point and at different moments can be obtained by applying a mathematical difference method. The dynamic temperature of the annulus at any well depth and the dynamic temperature distribution at any moment in the actual drilling process on site can be obtained, and the method can be applied on site.
The method can measure the original formation temperature, the dynamic temperature change and the static temperature in the shaft, the temperature of fluid (or drilling fluid) in the shaft and the temperature increasing quantity of the fluid, and predict the dynamic change characteristics of the formation and the shaft under different working conditions in the well.
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In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the drawings needed to be used in the embodiments will be briefly described below, it should be understood that the following drawings only illustrate some embodiments of the present invention and therefore should not be considered as limiting the scope, and for those skilled in the art, other related drawings can be obtained according to the drawings without inventive efforts.
FIG. 1 is a schematic diagram of a wellbore after surface drilling and a temperature parameter profile thereof according to an embodiment of the present invention;
FIG. 2 is a schematic diagram of a first and second open well bores and a distribution diagram of temperature parameters according to an embodiment of the present invention;
FIG. 3 is a schematic diagram of a first, second and third opening wellbore and temperature parameter profiles provided in accordance with an embodiment of the present invention;
FIG. 4 is a graph of regression data for formation temperature for a full interval after three times of wireline measurements, according to an embodiment of the present invention;
FIG. 5 is a graph of the static temperature profile of an empty wellbore and the static temperature profile of an annulus provided by an embodiment of the present invention;
FIG. 6 is a dynamic single point well depth-temperature profile provided by an embodiment of the present invention;
FIG. 7 is a dynamic profile of multi-point well depth versus temperature provided by an embodiment of the present invention;
FIG. 8 is a temperature increase distribution curve of the drilling fluid circulation obtained by the temperature measuring nipple C' in FIG. 7;
FIG. 9 is a full well cycle temperature increase curve at different times provided by embodiments of the present invention;
FIG. 10 is a plot of annular dynamic temperature versus time for an intentional depth point provided by an embodiment of the present invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below. The examples, in which specific conditions are not specified, were conducted under conventional conditions or conditions recommended by the manufacturer. The reagents or instruments used are not indicated by the manufacturer, and are all conventional products available commercially.
The invention relates to the specific terms and definitions:
original formation temperature and distribution-the temperature of the formation at a certain depth point without any disturbance, and the distribution of the original formation temperature with depth;
dynamic formation temperature and distribution-during the drilling process, the drilling fluid circulation disturbs the formation temperature of the near well zone and then the formation temperature and the temperature are distributed along with the depth;
annular dynamic temperature and distribution-the temperature and temperature distribution of the annular fluid between the outer wall of the drill string in the well and the wall of the well during circulation of the drilling fluid;
annular static temperature and distribution-during the drilling fluid circulation is stopped, when the dynamic formation temperature distribution is recovered to the original formation temperature distribution, the temperature and the temperature of annular liquid between the outer wall of the drill string and the well wall are distributed along with the depth;
dynamic temperature and distribution of empty wellbores-wellbore temperature and temperature distribution under the condition of dynamic formation temperature distribution, namely, during the process that the formation temperature is gradually recovered to the original formation temperature, the wellbore temperature and temperature distribution under the condition that no drill string exists in the wellbore;
and (3) the static temperature and distribution of the empty shaft, namely the temperature and distribution of the shaft in the condition of no drill column in the shaft after the dynamic formation temperature distribution is restored to the original ground temperature distribution.
The parameters required to be obtained from the device and the tool of the invention are as follows:
the well depth, time (including the time for drilling and stopping drilling) and drilling time can be obtained by comprehensive logging information;
measuring temperature after tripping, namely carrying out temperature measurement by using a cable winch or a steel wire winch with recorded depth and carrying a temperature measurement device (a cable type temperature measurement device) which is recorded at regular time and stored underground so as to obtain the temperature distribution condition of a shaft after tripping;
a temperature measuring device (for example, a temperature measuring nipple) capable of measuring and storing in real time is installed on the drill bit, and data is played back after the drill bit is tripped out, so that the temperature distribution condition of the well casing in the process of drilling is obtained.
According to the well depth and well bore structure distribution, at least a plurality of temperature measuring devices which can be measured and stored in real time are installed at proper positions on a drill string so as to obtain the temperature condition of the well bore at different depth points in the drilling process.
The method for measuring the virgin formation temperature, the empty wellbore static temperature, the annulus static temperature and the annulus dynamic temperature according to the embodiment of the invention is specifically described below.
A method of measuring virgin formation temperature, comprising:
after the well is opened and the thermodynamic equilibrium between the fluid in the well bore and the stratum is reached, the cable temperature measuring device is lowered into the opened well, and the relation between the temperature detected by the cable temperature measuring device and the well depth is the static temperature distribution of the opened well bore.
And (4) performing secondary open well drilling, and after the fluid of the well bore and the stratum reach thermodynamic equilibrium, putting a cable type temperature measuring device into the secondary open well to obtain the static temperature distribution of the secondary open well bore.
And (3) performing three-opening well drilling, and when the fluid of the shaft and the stratum reach thermodynamic equilibrium, putting a cable type temperature measuring device into the three-opening well to obtain the static temperature distribution of the three-opening shaft.
And fitting the static temperature distribution of the first open hole shaft, the static temperature distribution of the second open hole shaft and the static temperature distribution data of the third open hole shaft to obtain the original formation temperature distribution of the whole well section.
In other words, after a drill is completed, after the drill is tripped out, the wellbore fluid (drilling fluid) and the stratum reach thermodynamic equilibrium, namely, after the temperature of the wellbore fluid is close to the temperature of the stratum, the cable type temperature measuring device is put into the well to obtain the temperature of the static fluid, and the well depth is obtained through comprehensive logging information; the distribution of the well depth and the static fluid temperature is the static temperature distribution of an open well cylinder.
And obtaining the static temperature distribution of the second-opening-and-closing well bore and the static temperature distribution of the third-opening-and-closing well bore in the same way. And fitting the static temperature distribution of the first open hole shaft, the static temperature distribution of the second open hole shaft and the static temperature distribution data of the third open hole shaft to obtain the original formation temperature distribution of the whole well section.
In the embodiment of the invention, the condition that the wellbore fluid and the formation reach thermodynamic equilibrium refers to the condition that the temperature of the wellbore fluid is close to the temperature of the formation.
The cable type temperature measuring device in the embodiment of the invention is a cable type temperature measuring device (such as a thermocouple thermometer) carried by a cable winch or a wire winch.
It is understood that in other embodiments of the present invention, the whole wellbore section may need four-open wellbore, five-open wellbore, etc., and the static temperature distribution data of the multiple-open wellbore may be fitted to obtain the original formation temperature distribution of the whole wellbore section.
After the drilling is finished, a drill string is not arranged in the well, the wellbore fluid does not circulate, the wellbore fluid and the stratum reach thermodynamic equilibrium after the well is static for a long enough time (for example, more than 6 hours), namely the temperature of the wellbore fluid is close to the temperature of the stratum, at the moment, a cable-type temperature measuring device is put in, the temperature of the wellbore static fluid can be obtained, namely the temperature of the wellbore fluid at the moment of the static temperature distribution of the empty wellbore is very close to the temperature of the original stratum.
The method provided by the embodiment of the invention can obtain the original formation temperature of any well depth in the actual drilling process on site, and can be applied to the site.
Further, in other embodiments of the present invention, multiple temperatures may be measured for the entire interval.
1. Temperature measurement at open-hole section
FIG. 1 is a schematic diagram of a wellbore after surface drilling and a temperature parameter profile thereof according to an embodiment of the present invention; please refer to fig. 1.
A temperature measuring device (temperature measuring short section) is arranged near a drill bit, the temperature measuring short section records the temperature distribution condition of a shaft in the drilling process in the first drilling process, the well depth where the drill bit is located can be known by combining logging information, and the actual measurement annulus dynamic temperature distribution (the line in figure 1 is the actual measurement of drilling) in the first drilling process is obtained. After drilling is finished, pulling out the drill bit, and recording the temperature distribution condition of the shaft in real time during the pulling-out process by the temperature measuring short circuit, namely the dynamic temperature distribution of the empty shaft (the central line of figure 1 is used for actually measuring the pulling-out process); after the drilling is finished, after the wellbore fluid and the stratum gradually reach thermodynamic equilibrium, namely the wellbore fluid temperature gradually approaches to the stratum temperature, the cable type well temperature logging device is put into the well to obtain the static fluid temperature, namely the static temperature distribution of the open wellbore (the line in the figure 1 is measured in a cable type, and the full rest means dynamic repeated measurement until the temperature is basically unchanged), and the wellbore fluid temperature at the moment is very close to the original stratum temperature.
2. Two-well-interval temperature measurement
FIG. 2 is a schematic diagram of a two-open well bore and temperature parameter profiles according to an embodiment of the present invention; please refer to fig. 2.
In the second starting drilling process, a temperature measuring short circuit arranged near a drill bit is lowered to the first starting shaft bottom along with a drill string, in the lowering process, the temperature measuring short circuit records different lowering time and shaft temperature data, and the shaft temperature distribution condition in the lowering process of the first drilling bit can be obtained under the condition of the known lowering speed of the drill bit, namely the actual measurement of the empty shaft dynamic temperature distribution in the first drilling (the first drilling actual measurement in the central line of figure 2); the time from the first drilling to the second drilling is not long, and at the moment, the fluid in the well bore and the stratum do not reach a thermodynamic equilibrium state, heat exchange occurs between the fluid in the well bore and the stratum, and the temperature of the well bore is changed, namely the dynamic temperature of the empty well bore.
The drill bit starts to drill after entering the first well bottom, temperature data in a shaft can be continuously recorded due to the temperature measuring short circuit, the well depth of the drill bit can be known by combining logging information, and the measured annulus dynamic temperature distribution (the central line of figure 2 is drilled and measured) of the second well can be obtained; pulling out the second cut drill after reaching the designed position, and recording dynamic temperature distribution of the first cut and the second cut of the hollow well casing in the pulling out process by the temperature measuring short circuit (the central line of the figure 2 is actually measured in the pulling out process); after the drilling is finished, after the wellbore fluid and the stratum reach thermodynamic equilibrium, namely the temperature of the wellbore fluid is close to the temperature of the stratum, a cable type well temperature logging device is put into the well to obtain the static fluid temperature, namely the static temperature distribution of the two-way open empty wellbore (the line r in the figure 2 is cable type measurement).
3. Three-throw well section temperature testing method
FIG. 3 is a schematic diagram of a first, second and third opening wellbore and temperature parameter profiles provided in accordance with an embodiment of the present invention; please refer to fig. 3.
In the process of starting drilling with the three-opening, a temperature measuring short circuit arranged near a drill bit is lowered to the bottom of the two-opening well along with a drill column, in the lowering process, the temperature measuring short circuit records different lowering time and shaft temperature data, and the shaft temperature distribution condition in the lowering process of the two-opening drill bit can be obtained under the condition of the known lowering speed of the drill bit, namely the actual measurement of the dynamic temperature distribution of the empty shaft in the two-opening drilling (line 1 in fig. 3 is actually measured in the lowering process); in detail, the time from the second-cut drilling to the third-cut drilling is not long, at the moment, the wellbore fluid and the stratum do not reach a thermodynamic equilibrium state, heat exchange occurs between the wellbore fluid and the stratum, and the wellbore temperature changes, namely the dynamic temperature of the empty wellbore.
The drill bit starts to drill after entering the second-cut well bottom, temperature data in a shaft can be continuously recorded due to the temperature measuring short circuit, the well depth of the drill bit can be known by combining logging information, and the measured annular space dynamic temperature distribution of the third-cut well can be obtained (the line of figure 3 is the measured drilling); three-way drilling is carried out until the designed layer position is reached, and the dynamic temperature distribution of the hollow shaft barrel from one way to three ways in the drilling process is recorded by a temperature measuring short circuit (the line of figure 3 and actual measurement of the drilling is carried out); after the drilling is finished, after the wellbore fluid and the stratum reach thermodynamic equilibrium, namely the wellbore fluid temperature approaches the stratum temperature, the wellbore fluid is put into a cable type well temperature logging device to obtain the static fluid temperature, namely the static temperature distribution of the three-opening empty wellbore (line (r) cable type measurement in figure 3).
After the first, second and third openings are drilled, the temperature measurement data recorded by the cable-running well temperature logging device is obtained under the condition that the well bore fluid and the stratum around the well wall reach a thermodynamic equilibrium state after the well bore is fully static. Thus, the measured wellbore fluid temperature profile (i.e., the one-shot, two-shot, and three-shot static temperature profiles) is substantially equal to the virgin formation temperature.
FIG. 4 is a graph of regression data for formation temperature for a full interval after three times of wireline measurements, according to an embodiment of the present invention; and connecting and fitting the data recorded by the cable type well temperature device with the open hole section for one-way opening, two-way opening and three-way opening to obtain the original formation temperature of the whole well section, as shown in figure 4.
The invention also provides a technical scheme that:
a method of measuring static temperature of an empty wellbore, comprising: and after the well drilling is finished, when the fluid in the well bore and the stratum reach thermodynamic equilibrium, a cable type temperature measuring device is put into the well to obtain the static temperature distribution of the empty well bore.
As mentioned above, the static temperature and distribution of the empty wellbore refers to the wellbore temperature and distribution in the wellbore without a drill string after the dynamic formation temperature distribution is restored to the original ground temperature distribution.
In the present embodiment, the three-throw empty-wellbore static temperature distribution is used as the empty-wellbore static temperature distribution. In other embodiments, the last wireline measurement is taken as the empty wellbore static temperature profile.
As well depth increases during drilling, wellbore temperature also increases. Under the common conditions, the temperature of a target layer is highest, and due to the fact that the drilling working condition of the target layer is complex, and reservoir fractures and pores develop, the static temperature of an empty shaft and the static temperature distribution of an annulus are difficult to accurately obtain. Therefore, the invention also provides a method for measuring the static temperature of the empty well cylinder and a method for measuring the static temperature of the annulus.
FIG. 5 is a graph of the static temperature profile of an empty wellbore and the static temperature profile of an annulus provided by an embodiment of the present invention; please refer to fig. 5.
A method of measuring static temperature of an empty wellbore, comprising: and after the well drilling is finished, when the fluid in the well bore and the stratum reach thermodynamic equilibrium, a cable type temperature measuring device is put into the well to obtain the static temperature distribution of the empty well bore.
As mentioned above, the static temperature and distribution of the empty wellbore refers to the wellbore temperature and distribution in the wellbore without a drill string after the dynamic formation temperature distribution is restored to the original ground temperature distribution.
In the present embodiment, the three-throw empty-wellbore static temperature distribution is used as the empty-wellbore static temperature distribution. In other embodiments, the last wireline measurement is taken as the empty wellbore static temperature profile.
A method for measuring the static temperature of an annular space comprises the following steps: after drilling, after the fluid in the shaft and the stratum reach thermodynamic equilibrium, arranging the temperature measuring device in a drill column, putting the drill column into the well, standing for 4-6 hours, taking out the drill column, and taking the relation between the temperature recorded by the temperature measuring device and the well depth as the annular static temperature.
As mentioned above, the annular static temperature and distribution refers to the distribution of the temperature and temperature of the annular liquid between the outer wall of the drill string and the well wall along with the depth when the dynamic formation temperature distribution is restored to the original formation temperature distribution during the drilling fluid circulation stopping period.
The dynamic temperature and distribution of the empty shaft refer to the temperature and temperature distribution of the shaft under the condition of dynamic formation temperature distribution, namely, the formation temperature is recovered to the original formation temperature, and the shaft is not provided with a drill column in the shaft.
A method for measuring dynamic temperature of annular space comprises the following steps: installing a temperature measuring device on a drill string, wherein before the drill string drills: t is t0At all times, the temperature measuring device is at the well depth H0At position, temperature T0(ii) a Drilling is carried out, t1At the moment, the drill string drills to the well depth H1At a temperature of T1(ii) a At t0-t1And (3) recording time and well depth (T-H) relation data by using time period and logging data, recording time and annulus temperature (T-T) data by using a temperature measuring device, and synthesizing the data on the two planes to obtain a time-well depth-temperature (T-H-T) space line.
The method provided by the invention can be used for combining temperature data obtained by a temperature measuring device (temperature measuring short section) when the annular temperature distribution under the condition of a shaft fluid circulation state can be obtained in detail, so that the distribution of the annular dynamic temperature at any time point along with the well depth and the distribution of the annular dynamic temperature at any depth point along with the time can be obtained.
Projecting a time-well depth-temperature (T-H-T) space line at T0H-T plane, i.e. obtained at T0Time of day, interval H0-Hn(example ofSuch as well section H0-H1) Inner temperature profile.
Similarly, the time-well depth-temperature (T-H-T) space line is projected on T-H0-T plane, time-temperature line at a certain depth can be obtained.
In this embodiment, the well is a three-way well, and it is understood that in other embodiments of the present invention, the well may be any one of a one-way well, a two-way well, or a four-way well.
FIG. 6 is a dynamic single point well depth-temperature profile provided by an embodiment of the present invention; please refer to fig. 6.
A temperature measuring device (temperature measuring nipple) is installed on the drill string, and the temperature measuring device is defined as B' as shown in fig. 6. The data measured by the temperature measuring device is the depth of the three openings (t)0Time point) B' is located at well depth H0At a temperature of T0(ii) a After three drills are finished (t)1Time of day), as the wellbore deepens, the position of point B' in the wellbore moves to B, i.e., the well depth H1At a temperature of T1. At t0-t1In the time period, the logging data records the relation data of time and well depth, the temperature measuring device records the relation data of time and annular temperature (dynamic temperature and drilling temperature), and the data on the two planes are synthesized to obtain a time-well depth-temperature space line. The line is projected to t0The H-T plane, then the value at T can be obtained0When is, corresponding to H1Temperature values of the depth points. Connection t0And t1Temperatures at two time points are then obtained at t0At the moment, in the well depth section H0-H1The temperature distribution in the chamber. In the drilling process, the depth point of the temperature measuring device is continuously increased along with the drilling, and t can be recorded at the same timenWell depth at time HnAnd temperature Tn. Projecting these data points all at t0the-H-T plane can be obtained at T0At time, interval of well is H0-HnTemperature distribution profile of (a). Therefore, the annular temperature distribution condition of the well section corresponding to the travel distance of the temperature measuring device at the same moment can be obtained by the method, as shown in fig. 6.
In the same way, t0Projecting the temperature measurement data of the moment to t1The plane of the moment can obtain t1Time of day is H in the well section0-H1Temperature distribution profile of (a). By the same token, t can be deduced1And at a time point, measuring the annular temperature distribution condition of the well section corresponding to the travel distance of the temperature measuring nipple. Synthesis of t0And t1The obtained temperature profile can obtain the annular temperature distribution (distribution of annular dynamic temperature year well depth) of the measurement well section at different time points.
Further, in order to obtain the annular dynamic temperature distribution of the whole well section, a plurality of temperature measuring devices can be installed on the drill string. FIG. 7 is a dynamic profile of multi-point well depth versus temperature provided by an embodiment of the present invention; please refer to fig. 7.
In the three-opening drilling process, three temperature measuring short joints are installed on a drill string, and one temperature measuring short joint is installed near a drill bit, wherein the number of the temperature measuring short joints is 4 (C, B, A, O respectively). Data measured by three temperature measuring short sections on a drill string and data obtained by one temperature measuring short section near a drill bit are drawn on a well depth-temperature-time space coordinate, 4 trajectory lines are respectively obtained on a temperature-time plane and a well depth-time plane, so that the dynamic change relation of the well depth-temperature of 4 different time points is obtained by the obtaining method, and the dynamic temperature distribution of the annulus of the whole well section at different time points is fitted.
At the beginning of drilling, the temperature of the temperature measurement point increases with time, but this increase involves two factors: on one hand, the well depth is increased, and the formation temperature is higher, so that the annular temperature is increased; on the other hand, as the cycle time increases, bottom hole heat is carried to the wellhead, which increases the upper interval annulus temperature, but decreases the lower interval temperature.
In this example, the drilling fluid temperature rise value is measured.
Specifically, after drilling, after the thermodynamic equilibrium between the fluid in the shaft and the stratum is achieved, arranging the temperature measuring device on a drill column, putting the drill column into the well, standing for 4-6 hours, taking out the drill column, wherein the relation between the temperature recorded by the temperature measuring device and the well depth is the annulus static temperature;
according to the time of the whole well-sectionDeep-temperature space line, obtained: t is t1Time of day, well depth H1At a temperature of T1；T1And the well depth H1Difference of annular static temperature, i.e. well depth H1Circulating the drilling fluid to t1The drilling fluid temperature increase value at each moment; and drawing the relationship between the drilling fluid temperature increase value and the well depth.
Further, a plurality of temperature measuring devices are arranged on the drill string and are arranged along the length direction of the drill string; and drawing the temperature increasing values of the drilling fluid in the whole well section at different moments according to data measured by the plurality of temperature measuring devices.
According to the temperature increasing value of the drilling fluid in the whole well section: and drawing temperature increments delta T of the H ' at different moments according to intersection values of data measured by the plurality of temperature measuring devices and the given well depth H ', and drawing the temperature increments of the H ' at different moments on a delta T-T graph, so as to obtain the change of the dynamic temperature of the annulus at any depth point along with time.
FIG. 8 is a temperature increase distribution curve of the drilling fluid circulation obtained by the temperature measuring nipple C' in FIG. 7; please refer to fig. 8.
For the temperature measuring nipple C' in FIG. 7; before drilling, the temperature of the empty well shaft and the static temperature of the annulus can be obtained through the cable type temperature measuring device and the temperature measuring short section.
As mentioned above, the acquisition is performed at different cycle times (drilling different times) t1And t2The dynamic circulation temperature distribution condition of the annular space can be respectively obtained. t is t1The dynamic temperature of the annulus at the moment is subtracted by the static temperature of the annulus at the same well depth, and the difference is the circulation time t of the fluid (drilling fluid) at the depth1Temperature rise value after time t1-t0That is, the well depth is H0Drill to H1Time of (d). The same can be obtained at t2While, from well depth H1To H2The annular temperature increases. Therefore, a series of measured drilling fluid circulation temperature increase values of the upper well section are obtained by the method. Similarly, for the lower well section, the temperature decrease value at the time point can be obtained according to the method, and the temperature change condition of the whole well section can be drawn, as shown in fig. 8.
FIG. 9 is a full well cycle temperature increase curve at different times provided by embodiments of the present invention; FIG. 10 is a plot of annular dynamic temperature versus time for an intentional depth point provided by an embodiment of the present invention.
In this embodiment, 4 temperature measuring nipples (C, B, A, O, respectively) are provided, and the temperature increase value (or temperature decrease value) caused by circulation of the drilling fluid at different times (corresponding to different depths) of each temperature measuring nipple is plotted on a Δ T-H diagram, and in this embodiment, results at 6 time points are obtained (as shown in fig. 9); and fitting a curve of the circulating temperature rise of the whole well at different moments by referring to the trend line of the static temperature distribution of the empty well barrel through the points of 4 temperature measuring nipples on the delta T-H diagram at the same moment to obtain the distribution of the dynamic temperature of the annulus along with the well depth at any moment. As shown in fig. 9.
Further, from the results of fig. 9, if one wants to find the cyclic temperature rise values of a given well depth H' at different times, as shown in fig. 9: and (4) making a vertical line at the point H 'to cross the delta T-H line at different times to obtain the temperature increment of the point H' at different moments. And (3) drawing the temperature increment of the H' at different depths on the delta T-T graph to obtain the change of the dynamic temperature of the annulus at any depth point along with the time, as shown in figure 10.
Further, the temperature increment Δ T at any time within the actual elapsed cycle time can be obtained by applying the difference method; the temperature increase Δ T outside the actual elapsed cycle time can be determined using extrapolation methods (limited range).
The method is a set of thinking and a method for acquiring the formation temperature and the shaft temperature by the test data of the temperature measuring short section and the cable type well temperature logging device, but in fact, the dynamic change characteristics of the formation and the shaft temperature under different working conditions in the well can be predicted by a method of combining the actual measurement data with a mathematical model.
In summary, the original formation temperature, the dynamic temperature change and the static temperature in the wellbore, the temperature of the fluid (or drilling fluid) in the wellbore and the temperature increase amount of the fluid can be measured by the method, and the dynamic change characteristics of the formation and wellbore temperatures under different working conditions in the well can be predicted.
The above description is only a preferred embodiment of the present invention and is not intended to limit the present invention, and various modifications and changes may be made by those skilled in the art. Any modification, equivalent replacement, or improvement made within the spirit and principle of the present invention should be included in the protection scope of the present invention.
Claims (7)
1. A method for measuring dynamic temperature of annular space is characterized by comprising the following steps: installing a temperature measuring device on a drill string, wherein before drilling the drill string: t is t0At all times, the temperature measuring device is at the well depth H0At position, temperature T0(ii) a Drilling is carried out, t1At the moment, the drill string drills to the well depth H1At a temperature of T1(ii) a At t0-t1And the time period, the logging data records the relation data of time and well depth T-H, the temperature measuring device records the time and annulus temperature T-T data, and the data on the two planes are synthesized to obtain a time-well depth-temperature T-H-T space line.
2. The method of claim 1, wherein the time-well depth-temperature T-H-T space line is projected at T0H-T plane, i.e. obtained at T0Time of day, interval H0-H1Inner temperature profile.
3. The method of claim 1, wherein the drill string borehole can be any one of a one-shot borehole, a two-shot borehole, or a three-shot borehole.
4. The method of claim 1, wherein a plurality of temperature measuring devices are mounted on the drill string, and are arranged along the length of the drill string; and drawing a time-depth-temperature space line of the whole well section by using data measured by the plurality of temperature measuring devices.
5. The method of claim 4, wherein the annular dynamic temperature is measured,
after drilling, after the thermodynamic equilibrium between the fluid in the shaft and the stratum is achieved, arranging a temperature measuring device on a drill string, putting the drill string into the well, standing for 4-6 hours, and taking out the drill string, wherein the relation between the temperature recorded by the temperature measuring device and the well depth is the annulus static temperature;
obtaining the following data according to the full-interval time-well depth-temperature space line: t is t1Time of day, well depth H1At a temperature of T1；T1And the well depth H1Difference of annular static temperature, i.e. well depth H1Circulating the drilling fluid to t1The drilling fluid temperature increase value at each moment; and drawing the relationship between the drilling fluid temperature increase value and the well depth.
6. The method of claim 5, wherein a plurality of temperature measuring devices are mounted on the drill string, and arranged along the length of the drill string; and drawing the temperature increasing values of the whole well section drilling fluid at different moments according to data measured by the plurality of temperature measuring devices.
7. The method for measuring the dynamic temperature of the annulus according to claim 6, wherein according to the temperature increase value of the full-interval drilling fluid: and calculating the temperature increment delta T of the H ' at different moments according to the intersection point value of the data measured by the plurality of temperature measuring devices and the given well depth H ', and drawing the temperature increments of the H ' at different moments on a delta T-T graph, thereby obtaining the change of the dynamic temperature of the annulus at any depth point along with time.
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| CN108871620B (en) * | 2018-06-01 | 2021-03-09 | 中国石油天然气股份有限公司 | Distributed temperature measurement optical fiber depth calibration method |
| CN109101703B (en) * | 2018-07-23 | 2022-07-05 | 中国石油集团川庆钻探工程有限公司 | Method for predicting borehole temperature by regions and sections based on well cementation big data |
| CN108930534B (en) * | 2018-08-10 | 2020-07-17 | 中国石油大学(北京) | Method and device for correcting temperature influence of nuclear magnetic resonance formation while drilling |
| CN113586039A (en) * | 2021-08-02 | 2021-11-02 | 西南石油大学 | Method for monitoring overflow and leakage positions in real time based on distributed optical fiber |
| CN115293066B (en) * | 2022-08-09 | 2023-09-01 | 西南石油大学 | Gas well temperature field calculation method considering stratum seepage heat transfer effect |
| CN115935860B (en) * | 2023-03-09 | 2023-07-18 | 中国石油天然气股份有限公司 | Oil well yield determination method and system |
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Application publication date: 20180327 Assignee: CHENGDU HAOHAN WELL COMPLETION & LOGGING SCIENCE & TECHNOLOGY CO.,LTD. Assignor: SOUTHWEST PETROLEUM University Contract record no.: X2022980028664 Denomination of invention: Measurement methods of original formation temperature, static temperature of empty wellbore, static temperature of annulus and dynamic temperature of annulus Granted publication date: 20210323 License type: Common License Record date: 20221226 |