CN112343573B - Method for predicting yield of condensate gas well - Google Patents
Method for predicting yield of condensate gas well Download PDFInfo
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- CN112343573B CN112343573B CN201910725363.4A CN201910725363A CN112343573B CN 112343573 B CN112343573 B CN 112343573B CN 201910725363 A CN201910725363 A CN 201910725363A CN 112343573 B CN112343573 B CN 112343573B
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- 238000000034 method Methods 0.000 title claims abstract description 48
- 238000004519 manufacturing process Methods 0.000 claims abstract description 86
- 239000003129 oil well Substances 0.000 claims description 15
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- 238000004364 calculation method Methods 0.000 claims description 7
- 238000005516 engineering process Methods 0.000 abstract description 4
- 238000007620 mathematical function Methods 0.000 abstract description 4
- 239000007789 gas Substances 0.000 description 234
- 239000003921 oil Substances 0.000 description 73
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 12
- 238000005259 measurement Methods 0.000 description 9
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- 239000000203 mixture Substances 0.000 description 6
- 239000003345 natural gas Substances 0.000 description 6
- 239000003208 petroleum Substances 0.000 description 6
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- 239000010779 crude oil Substances 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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Abstract
According to the method for predicting the yield of the condensate gas well, provided by the application, the yield prediction standard curve of the condensate gas well is established, the abscissa of the yield prediction standard curve is the yield of the condensate gas well, the ordinate is the kilometer heat loss of the shaft, the mathematical function relation between the yield of the condensate gas well and the kilometer heat loss of the shaft is obtained according to the yield prediction standard curve, the kilometer heat loss of the shaft on the date to be detected is obtained, and the numerical value is input into the function corresponding to the yield prediction standard curve, so that the yield on the date to be detected of the condensate gas well can be uniquely determined by virtue of the function relation, the yield of the condensate gas well can be continuously obtained without the need of well logging technology team logging, and the production system of the condensate gas well can be timely adjusted according to the yield of the condensate gas well.
Description
Technical Field
The application relates to petroleum exploitation technology, in particular to a method for predicting the yield of a condensate gas well.
Background
For condensate reservoirs produced in a depletion mode, daily yield is controlled to be too small, condensate is trapped in a seepage passage of the stratum, the stratum is greatly lost in oil, daily yield is controlled to be too large, the energy generation is accelerated to be depleted, reverse condensate occurs at the bottom of a well, and the recovery ratio of the condensate is affected. The method is characterized in that the yield of the condensate gas field is reasonably determined and regulated, the loss of stratum condensate oil is reduced, and the method is a key problem for improving the economic benefit of the condensate gas field.
In the prior art, the production data of the condensate gas field is mainly obtained through a metering separator, the metering separator is arranged on a test production single well to record the production data of the single well, after an oil-gas mixture enters the metering separator through a pipeline, the oil-gas mixture is separated, the separated oil falls into the lower part of the metering separator by gravity, is discharged through an oil discharge pipe, the gas rises due to small density, the measurement is carried out through an air outlet pipeline at the top of the metering separator, the production measurement data of the condensate gas field is displayed on an instrument of the metering separator, and the production data is recorded by a resident well technical team at regular time.
However, because the well logging technology team has high well logging safety risk, only intermittent well logging metering can be realized, and the single well yield of the condensate gas field cannot be continuously determined, so that the production system of the condensate gas well cannot be timely adjusted according to the single well yield of the condensate gas field.
Disclosure of Invention
The embodiment of the application provides a method for predicting the yield of a condensate gas well, which is used for solving the problem that the production system of the condensate gas well cannot be adjusted in time according to the single well yield of the condensate gas field because the single well yield determination method of the condensate gas field is not continuous.
The embodiment of the application provides a method for predicting the yield of a condensate gas well, which comprises the following steps: establishing a yield prediction standard curve of the condensate gas well, wherein the yield prediction standard curve comprises the yield of the condensate gas well and the kilometer heat loss of a shaft; and acquiring the kilo-meter heat loss of the shaft on the date to be measured of the condensate gas well, inputting the kilo-meter heat loss of the shaft on the date to be measured of the condensate gas well into the yield prediction standard curve, and acquiring the yield on the date to be measured of the condensate gas well.
Optionally, the establishing a production prediction standard curve of the condensate gas well includes: fitting the actual daily output before the date of the condensate gas well to be measured and the kilometer heat loss of the shaft corresponding to the actual daily output, and establishing a yield prediction standard curve of the condensate gas well.
Optionally, the fitting the actual daily output before the date of the condensate gas well to the wellbore kilometer heat loss corresponding to the actual daily output includes: fitting all actual daily production before the date of the condensate gas well to be measured and the heat loss of the shaft kilometers corresponding to the actual daily production.
Optionally, obtaining the wellbore kilometer heat loss comprises: and the bottom hole temperature of the condensate gas well is different from the wellhead temperature, and the ratio of the difference value to the well depth data is the heat loss of the well shaft kilometer.
Optionally, the wellhead temperature is obtained by a temperature sensor mounted at the wellhead of the condensate well.
Optionally, the temperature sensor of the condensate gas well wellhead is arranged on the production wing of the christmas tree and is positioned at the outlet end of the choke.
Optionally, one of the oil and gas yields of the condensate gas well to be measured is obtained according to the yield of the condensate gas well to be measured, and the other one of the oil and gas yields of the condensate gas well to be measured is obtained through calculation according to the one of the oil and gas yields of the condensate gas well to be measured.
Optionally, the obtaining the one of the oil and gas yield of the date to be measured of the condensate gas well according to the yield of the date to be measured of the condensate gas well, and calculating the other one of the oil and gas yield of the date to be measured of the condensate gas well according to the one of the oil and gas yield of the date to be measured of the condensate gas well includes: the yield of the condensate gas well on the date to be measured is the gas yield of the condensate gas well on the date to be measured, the gas-oil ratio of the condensate gas well is obtained, and the oil yield of the condensate gas well on the date to be measured is calculated according to the gas-oil ratio and the gas yield of the condensate gas well on the date to be measured.
Optionally, the obtaining the one of the oil and gas yield of the date to be measured of the condensate gas well according to the yield of the date to be measured of the condensate gas well, and calculating the other one of the oil and gas yield of the date to be measured of the condensate gas well according to the one of the oil and gas yield of the date to be measured of the condensate gas well includes: the yield of the condensate gas well on the date to be measured is the oil yield of the condensate gas well on the date to be measured, the oil-gas ratio of the condensate gas well is obtained, and the gas yield of the condensate gas well on the date to be measured is calculated according to the oil-gas ratio and the oil yield of the condensate gas well on the date to be measured.
Optionally, the method further comprises: fitting the actual daily production of the condensate gas well on the date to be measured and the corresponding kilometer heat loss of the shaft to the production prediction standard curve to update the production prediction standard curve.
According to the method for predicting the yield of the condensate gas well, provided by the embodiment of the application, the yield prediction standard curve of the condensate gas well is established, the abscissa of the yield prediction standard curve is the yield of the condensate gas well, the ordinate is the kilometer heat loss of the shaft, a mathematical function relation exists between the yield of the condensate gas well and the kilometer heat loss of the shaft, the kilometer heat loss of the shaft on the date to be detected is obtained, the numerical value is input into a function corresponding to the yield prediction standard curve, the yield on the date to be detected of the condensate gas well can be uniquely determined by virtue of the function relation, the yield of the condensate gas well can be predicted by establishing the yield prediction standard curve of the condensate gas well, and the yield of the condensate gas well can be continuously obtained without a resident well, so that the production system of the condensate gas well can be timely adjusted according to the yield of the condensate gas well.
Drawings
In order to more clearly illustrate the embodiments of the application or the technical solutions of the prior art, the drawings which are used in the description of the embodiments or the prior art will be briefly described, it being obvious that the drawings in the description below are only some embodiments of the application, and that other drawings can be obtained according to these drawings without inventive faculty for a person skilled in the art.
FIG. 1 is a schematic flow chart of a first embodiment of a method for predicting production of a condensate well according to the present application;
FIG. 2 is a schematic diagram of a yield prediction curve of a method for predicting the yield of a condensate well according to the present application;
FIG. 3 is a schematic flow chart of a second embodiment of a method for predicting production of a condensate well according to the present application;
FIG. 4 is a schematic diagram of a second embodiment of a method for predicting production of a condensate well according to the present application;
FIG. 5 is a schematic flow chart of a third embodiment of a method for predicting production of a condensate well according to the present application;
fig. 6 is a schematic flow chart of a fourth embodiment of a method for predicting production of a condensate well according to the present application.
Reference numerals illustrate:
10: a tree;
101: producing wings by utilizing the christmas tree;
102: and a nipple.
Detailed Description
In order to make the above objects, features and advantages of the embodiments of the present application more comprehensible, the technical solutions of the embodiments of the present application will be described clearly and completely with reference to the accompanying drawings. It will be apparent that the described embodiments are only some, but not all, embodiments of the application. All other embodiments, which can be made by those skilled in the art based on the embodiments of the application without making any inventive effort, are intended to be within the scope of the application.
The following describes the technical scheme of the present application and how the technical scheme of the present application solves the above technical problems in detail with specific embodiments. The following embodiments may be combined with each other, and the same or similar concepts or processes may not be described in detail in some embodiments. Embodiments of the present application will be described below with reference to the accompanying drawings.
Fig. 1 is a schematic flow chart of an embodiment of a method for predicting production of a condensate gas well according to the present application, where the method of fig. 1 is performed by a device for predicting production of a condensate gas well, and the device for predicting production of a condensate gas well may be a server or a computer, and the embodiment of the present application is not limited thereto, and the method of the embodiment is shown in fig. 1:
s101: and (5) establishing a yield prediction standard curve of the condensate gas well.
S102: and acquiring the kilo-meter heat loss of the shaft of the condensate gas well on the date to be measured, inputting the kilo-meter heat loss of the shaft of the condensate gas well on the date to be measured into a yield prediction standard curve, and acquiring the yield of the condensate gas well on the date to be measured.
Wherein the production prediction standard curve comprises the production of a condensate gas well and the kilometer heat loss of a shaft.
Wherein the production may be gas production and/or oil production. Specifically, the yield of the condensate gas well on the date to be measured may be the gas yield of the condensate gas well on the date to be measured and/or the oil yield of the condensate gas well on the date to be measured.
The yield prediction standard curve may include gas yield of the condensate gas well and kilometer heat loss of the shaft, and correspondingly, the kilometer heat loss of the shaft on the date of the condensate gas well to be measured is input into the yield prediction standard curve, and the yield on the date of the condensate gas well to be measured is obtained, namely the gas yield of the condensate gas well. The yield prediction standard curve can also comprise the oil yield of the condensate gas well and the kilometer heat loss of the shaft, correspondingly, the kilometer heat loss of the shaft on the date of the condensate gas well to be detected is input into the yield prediction standard curve, and the yield on the date of the condensate gas well to be detected is obtained to be the oil yield of the condensate gas well, so that the embodiment of the application is not limited. The following examples are presented by way of illustration of production prediction standard curves including gas production from condensate wells and wellbore kilometer heat loss.
The method for predicting the production of the condensate gas well provided by the embodiment of the application can be applied to the production prediction of the condensate gas well in different development stages, such as a trial production stage and a development stage, and also can be applied to the production prediction of each single well of different condensate gas field blocks, such as a Tarim oilfield Diover block DN2-23 well.
The yield prediction standard curve is a trend line related to the yield of the condensate gas well and comprises a mathematical function relation. As shown in FIG. 2, the abscissa (X) of the production prediction standard curve represents the production of the condensate gas well, the ordinate (Y) represents the wellbore kilometer heat loss, and the wellbore kilometer heat loss of the condensate gas well on a certain day may correspond to the daily production value of the condensate gas well on the same day, for example, the wellbore kilometer heat loss of the condensate gas well on the 3 month 6 day is 10 ℃/km, the production on the 3 month 6 day is gas production, and the value thereof is 400000m 3 The coordinate point of the yield prediction standard curve for 3 months and 6 days is (400000, 10). It should be noted that each abscissa (X) value in the yield prediction standard curve uniquely corresponds to one ordinate (Y) value, and each ordinate (Y) value uniquely corresponds to one abscissa (X) value.
The trend of the production prediction standard curve represents the functional relation between the production of the condensate gas well and the kilometer heat loss of the shaft, and the functional relation can be linear or nonlinear. For example, the yield prediction standard curve shown in fig. 2 corresponds to the following functional relationship:
wellbore kilometer heat loss = -4.419 x ln (daily gas yield + 123894) +66.9232.
Alternatively, all individual wells in the condensate field correspond to a yield prediction curve, and by taking the yield of all individual wells in the condensate field and the kilometer heat loss from the wellbore, a yield prediction curve is obtained that is adapted to all individual wells in the condensate field.
Optionally, due to different geological structures of the condensate gas field blocks, parameters such as gas reservoir pressure, well depth data, fluid viscosity and the like of each condensate gas well are different, so that in order to reduce interference of geological factors and parameters of each condensate gas well on a yield prediction curve, the accuracy of the yield prediction curve is improved, and the condensate gas wells and the yield prediction curve adopt a one-to-one correspondence.
In this embodiment, by establishing a yield prediction standard curve of a condensate gas well, wherein the abscissa of the yield prediction standard curve is the yield of the condensate gas well, the ordinate is the kilometer heat loss of the shaft, according to the yield prediction standard curve, a mathematical function relationship existing between the yield of the condensate gas well and the kilometer heat loss of the shaft is obtained, the kilometer heat loss of the shaft on the date to be measured is obtained, and the numerical value is input into a function corresponding to the yield prediction standard curve, and by means of the function relationship, the yield on the date to be measured of the condensate gas well can be uniquely determined. Therefore, the production of the condensate gas well can be continuously obtained without logging in a logging technology team, and the production system of the condensate gas well can be timely adjusted according to the production of the condensate gas well.
Fig. 3 is a schematic flow chart of a second embodiment of a method for predicting gas condensate well production according to the present application, and fig. 3 is a description of a possible implementation of S101 further based on the embodiment shown in fig. 1, as shown in fig. 3:
s1011: fitting the actual daily output before the date of the condensate gas well to the heat loss of the shaft kilometer corresponding to the actual daily output, and establishing a yield prediction standard curve of the condensate gas well.
S102: and acquiring the kilo-meter heat loss of the shaft of the condensate gas well on the date to be measured, inputting the kilo-meter heat loss of the shaft of the condensate gas well on the date to be measured into a yield prediction standard curve, and acquiring the yield of the condensate gas well on the date to be measured.
And acquiring actual daily output before the date to be measured and a shaft kilometer heat loss value corresponding to the actual daily output, fitting by using the existing data, and establishing a yield prediction standard curve of the condensate gas well, so that the validity of the fitted data can be ensured, and the reliability of the yield prediction standard curve is improved.
The term "before date of measurement of a gas condensate well" refers to the period from the date of production to the date of measurement of the gas condensate well.
Wherein the actual daily yield may be an actual daily gas yield and/or an actual daily oil yield.
The actual daily production is the actual daily gas production, and the corresponding production prediction standard curve comprises the production of the condensate gas well and the kilometer heat loss of the shaft, namely the gas production of the condensate gas well and the kilometer heat loss of the shaft. The actual daily oil yield is the actual daily oil yield, and the corresponding yield prediction standard curve comprises the yield of a condensate gas well and the kilometer heat loss of a shaft, namely the oil yield and the kilometer heat loss of the shaft.
Alternatively, the actual daily output may be obtained by a metering method such as measuring volume or measuring weight.
Alternatively, the yield prediction standard curve may be obtained by Matlab, or Ansys fitting, so long as numerical analysis can be performed, which is not limited in the embodiment of the present application.
Wherein the actual daily production data and corresponding wellbore kilometer heat loss data before the date of condensate gas well testing includes, but is not limited to, the following possible implementations:
one possible implementation is as follows: and fitting N groups of actual daily output before the date to be measured of the condensate gas well and the kiloheat loss of the shaft corresponding to the actual daily output, wherein N is more than or equal to 1 and less than the number of all data groups before the date to be measured.
Specifically, the actual daily output of the N groups before the date of the condensate gas well to be measured and the heat loss of the shaft kilometer corresponding to the actual daily output can be data of any N days before the date of the condensate gas well to be measured, and the embodiment does not limit the date corresponding to the actual daily output and the heat loss of the shaft kilometer. For example: actual daily production and wellbore kilometer heat loss data for 10 consecutive days prior to the date to be measured may be selected.
Specifically, the actual daily output of the N groups before the date of the condensate gas well to be measured and the heat loss of the shaft kilometer corresponding to the actual daily output can be any N groups of data of any day before the date to be measured, and the embodiment does not limit the available data groups of any day. For example: only one set of data is available per day; alternatively, n sets of data may be obtained daily, n being an integer greater than 1.
Another possible implementation: fitting all actual daily production before the date of the condensate gas well to be measured and the heat loss of the shaft kilometers corresponding to the actual daily production.
And acquiring all actual daily output and corresponding shaft kilometer heat loss data before the date to be measured for numerical analysis, so that the number of fitted sample values is increased, the accuracy of a yield prediction standard curve is improved, and the accuracy of condensate gas well yield prediction is improved.
In this embodiment, before the date of measurement of the condensate gas well, actual daily output and data of the heat loss of the shaft kilometer corresponding to the actual daily output are obtained, the data are drawn into a coordinate system, a yield prediction standard curve is fitted through numerical analysis, the heat loss of the shaft kilometer on the date of measurement is obtained, the numerical value is input into the yield prediction standard curve, and the yield of the condensate gas well on the date of measurement can be uniquely determined by virtue of a functional relationship corresponding to the yield prediction standard curve. The actual daily output and the data of the heat loss of the shaft kilometers before the date of the condensate gas well to be measured are obtained, and the data are analyzed and processed to be fitted into the output prediction standard curve, so that the validity of the fitted data is ensured, the reliability of the output prediction standard curve is improved, and therefore, the output prediction precision is improved.
In the above embodiment, optionally, possible implementation manners of acquiring the heat loss of the kilometer of the shaft include: and (3) taking the difference between the bottom temperature of the condensate gas well and the wellhead temperature, wherein the ratio of the difference to the well depth data is the heat loss of the well shaft kilometers.
And the kilo-meter heat loss of the shaft is obtained through the ratio of the difference value of the bottom hole temperature and the wellhead temperature of the condensate gas well to the well depth data, so that the realization mode is simple and the calculation is simple.
Alternatively, the well depth data for each condensate well is fixed, and the well depth data for each condensate well may be obtained through a well history.
Typically the bottom hole temperature is fixed. The bottom of the condensate well is close to the stratum, the stratum temperature influences the bottom-hole temperature, and the stratum temperature change at the same depth is negligible, so that the bottom-hole temperature change is also negligible.
Among other ways to obtain wellhead temperature include, but are not limited to, the following several possible implementations:
one possible implementation manner is as follows: the wellhead temperature is obtained by arranging a temperature sensor at the wellhead position of the condensate gas well. The temperature sensor is connected with a remote terminal control device, and the remote terminal control device is connected with a data acquisition and monitoring control system in a central control room (or a remote workstation).
By arranging the temperature sensor at the wellhead of the condensate gas well, the wellhead temperature is known, the resident technical team is not required to reach the condensate gas well site, and only the data acquisition and monitoring control system computer of a central control room (or a remote workstation) is required to regulate and control, so that the safety risk caused by the on-site operation of the resident technical team is reduced, the physical health and life safety of the resident technical team are ensured, and the labor cost is saved; meanwhile, the wellhead temperature of the condensate gas well can be remotely monitored and recorded and transmitted in real time, and the working efficiency is improved.
The number of the arrangement of the temperature sensors may be one. Further alternatively, as shown in fig. 4, when the number of temperature sensors is one, the position of the temperature sensor at the wellhead of the condensate gas well may be set at the production wing 101 of the christmas tree and at the outlet end of the nozzle 102; the device can also be arranged at the front end of the oil nozzle or the rear end of the oil nozzle; the position of the temperature sensor at the wellhead of the condensate gas well can also be installed by technicians according to actual needs and experience.
Because the oil nozzle can control oil gas output, the flow rate of the oil gas mixture after being regulated is different, the heat emitted in the transmission process is also different, the temperature sensor is arranged on the production wing 101 of the christmas tree and is positioned at the outlet end of the oil nozzle 102, compared with the temperature sensor which is arranged at other positions, the wellhead temperature obtained by detection is more accurate, and the temperature sensor is simple to install.
The extracted oil-gas mixture flows from the petroleum production pipeline through the wellhead and then enters the production wing 101 of the christmas tree, flows into the nozzle 102 along the production wing 101 of the christmas tree, the temperature sensor detects the temperature of the oil-gas mixture flowing through the outlet end of the nozzle 102, thereby obtaining the wellhead temperature and outputting a temperature signal, the signal is sent to the remote terminal control device, the remote control device sends the received temperature signal to the data acquisition and monitoring control system in the central control room (or remote workstation), and the central control room control system converts the temperature signal into a digital value, displays the digital value on the display screen and records the digital value.
The number of the temperature sensors may be plural. Further alternatively, when the number of temperature sensors is plural, the positions of the temperature sensors at the wellhead of the condensate well may be provided at the production wing 101 of the christmas tree and arranged at circumferentially spaced intervals along the outlet end of the nozzle 102. The working principle is similar to that of one temperature sensor, except that the temperature sensor of the embodiment outputs a plurality of temperature signals, and finally the central control room control system receives the plurality of temperature signals and converts the plurality of signals into digital quantities respectively, records a plurality of temperature values, takes the average value as wellhead temperature and displays the wellhead temperature on a display screen.
Another possible implementation is: the wellhead temperature is obtained by arranging an electronic thermometer at the wellhead position of the condensate gas well, a temperature measuring element of the electronic thermometer is arranged at the outlet end of the oil nozzle 102, a display screen of the electronic thermometer is arranged at a remote workstation, and the temperature measuring element of the electronic thermometer is connected with the display screen.
The temperature measuring element of the electronic thermometer detects the temperature of the oil-gas mixture flowing through the outlet end of the oil nozzle 102, outputs a temperature signal, sends the temperature signal to a remote workstation, and the remote workstation control system converts the temperature signal into a digital quantity, displays the digital quantity on a display screen and records the digital quantity.
Alternatively, the bottom hole temperature is obtained by a pressure thermometer placed at the bottom of the condensate well.
The bottom hole temperature is obtained through the pressure type thermometer, and the bottom hole temperature measuring device is simple in structure and convenient to operate.
The pressure thermometer can be placed at the bottom of the well through a steel wire or a cable in the production test stage of the condensate gas well, and is taken out through the steel wire or the cable after metering is finished.
Fig. 5 is a schematic flow chart of a third embodiment of a method for predicting production of a condensate gas well according to the present application, and fig. 5 is a flowchart of any one of the embodiments shown in fig. 1 to 3, further, after obtaining the production of the condensate gas well on the date to be measured, the method may further include:
s103: and obtaining one of the oil and gas yields of the condensate gas well on the date to be measured according to the yield of the condensate gas well on the date to be measured, and calculating the other one of the oil and gas yields of the condensate gas well on the date to be measured according to the one of the oil and gas yields of the condensate gas well on the date to be measured.
According to the yield of the condensate gas well on the date to be measured, one of the oil and gas yields of the condensate gas well on the date to be measured is obtained, and then the one of the oil and gas yields of the condensate gas well on the date to be measured is directly calculated through a calculation mode, so that the method is simple in implementation mode and calculation.
Wherein, obtaining the oil and gas yield of the condensate gas well according to the yield of the condensate gas well on the date of measurement includes, but is not limited to, the following possible implementation modes:
s1031: the yield of the condensate gas well on the date to be measured is the gas yield of the condensate gas well on the date to be measured, the gas-oil ratio of the condensate gas well is obtained, and the oil yield of the condensate gas well on the date to be measured is calculated according to the gas-oil ratio and the gas yield of the condensate gas well on the date to be measured.
The gas-oil ratio refers to the amount of natural gas carried out per ton of crude oil produced by oil well production, wherein oil and gas are simultaneously discharged from the well. Therefore, the ratio of the gas yield to the oil yield of the condensate gas well is the gas-oil ratio (unit: m) 3 /m 3 )。
The gas-oil ratio of the condensate gas well is obtained by the following implementation modes:
one possible implementation is as follows: and (3) extracting a petroleum sample of the condensate gas well, testing the sample, and obtaining the gas-oil ratio according to the test result of the sample.
The method for extracting the petroleum sample can be oil tank sampling or pipeline sampling, and the embodiment does not limit the extraction method. Meanwhile, the present embodiment also does not limit the sample assay method, for example: distillation and centrifugation.
The way in which the petroleum sample is drawn may be a closed loop sampler. The closed loop sampler is closed in the whole process during petroleum sampling, avoids the change of the relative proportion of oil and gas caused by evaporation and the like, is safe and environment-friendly, and is simple and quick to operate.
Another possible implementation: and (3) extracting a natural gas sample of the condensate gas well, testing the natural gas sample, and obtaining the gas-oil ratio according to a sample testing result.
The sampling method of the natural gas sample may be a purge method, an evacuation container method, or a seal replacement method, which is not limited in this embodiment.
The natural gas sample vessel may be a stainless steel high pressure gas cylinder. Stainless steel has high corrosion resistance, is not easy to damage, and avoids the danger caused by the damage of a container of a natural gas sample in the transportation process.
Alternatively, the gas-to-oil ratio may be stable. The gas-oil ratio data of the condensate gas fields of different blocks are different, and the gas-oil ratio of the condensate gas fields with stable gas-oil ratios are the same and stable. The stable gas-oil ratio can be regarded as a constant, and can be obtained after one sampling test. When the gas-oil ratio is stable, the oil yield of the condensate gas well can be obtained by directly comparing the gas yield with the gas-oil ratio according to the gas yield of the condensate gas well, and the calculation is simple and quick, so that the cost is saved.
S1032: the yield of the condensate gas well on the date to be measured is the oil yield of the condensate gas well on the date to be measured, the oil-gas ratio of the condensate gas well is obtained, and the gas yield of the condensate gas well on the date to be measured is calculated according to the oil-gas ratio and the oil yield of the condensate gas well on the date to be measured.
The oil-gas ratio refers to the ratio (unit: m) of the oil yield to the gas yield of a condensate gas well at a certain temperature and pressure 3 /m 3 )。
The method for obtaining the gas-oil ratio of the condensate gas well is similar to the method for obtaining the gas-oil ratio of the condensate gas well, and the embodiment is not repeated here.
Alternatively, the gas-oil ratio may be stable. The stable gas-oil ratio can be regarded as a constant, and can be obtained after one sampling test. When the oil-gas ratio is stable, the gas yield of the condensate gas well can be obtained by directly comparing the oil yield with the oil-gas ratio according to the oil yield of the condensate gas well, and the calculation is simple and quick, so that the cost is saved.
For example: the yield of the condensate gas well on the date to be measured is the gas yield of the condensate gas well on the date to be measuredAn amount of 4000m 3 The gas yield of the condensate gas well is 4000m 3 The gas-oil ratio of the condensate gas well is 1m 3 /m 3 The ratio of gas yield to oil yield of the condensate gas well at a certain temperature and pressure is 1, so that the oil yield of the condensate gas well on the date to be measured is 4000m 3 。
Fig. 6 is a schematic flow chart of a fourth embodiment of a method for predicting the production of a condensate gas well according to the present application, and fig. 6 is a schematic flow chart of the fourth embodiment, further, after obtaining the oil and gas production of the condensate gas well on the date of measurement, the method may further include:
s104: fitting the actual daily production of the condensate well on the date to be measured and the corresponding heat loss of the well kilometers to the production prediction standard curve to update the production prediction standard curve.
Fitting the actual daily production and the corresponding wellbore kilometer heat loss to the production prediction standard curve can correct the error of the production prediction standard curve, thereby reducing the error of the subsequent predicted value.
The actual daily output of the condensate gas well on the date to be measured refers to the daily output obtained by actual exploitation of the condensate gas well on the date to be measured.
And acquiring the actual daily yield of the condensate gas well on the date to be measured and the corresponding shaft kilometer heat loss, and re-drawing the actual daily yield and the corresponding shaft kilometer heat loss in the obtained date to be measured into a coordinate system of a yield prediction standard curve, and obtaining a new yield prediction curve through fitting.
Finally, it should be noted that: the above embodiments are only for illustrating the technical solution of the present application, and not for limiting the same; although the application has been described in detail with reference to the foregoing embodiments, it will be understood by those of ordinary skill in the art that: the technical scheme described in the foregoing embodiments can be modified or some or all of the technical features thereof can be replaced by equivalents; such modifications and substitutions do not depart from the spirit of the application.
Claims (9)
1. A method for predicting condensate gas well production, comprising:
establishing a yield prediction standard curve of the condensate gas well, wherein the yield prediction standard curve comprises the yield of the condensate gas well and the kilometer heat loss of a shaft;
acquiring the kilo-meter heat loss of the shaft on the date to be measured of the condensate gas well, inputting the kilo-meter heat loss of the shaft on the date to be measured of the condensate gas well into the yield prediction standard curve, and acquiring the yield on the date to be measured of the condensate gas well;
the method for establishing the yield prediction standard curve of the condensate gas well comprises the following steps:
fitting the actual daily yield before the date of the condensate gas well to be measured and the kilometer heat loss of the shaft corresponding to the actual daily yield, and establishing a yield prediction standard curve of the condensate gas well;
wellbore kilometer heat loss = -4.419 x ln (daily gas yield + 123894) +66.9232.
2. The method of claim 1, wherein said fitting the actual daily production of the condensate gas well prior to the date it was measured to the wellbore kilometer heat loss corresponding to the actual daily production comprises: fitting all actual daily production before the date of the condensate gas well to be measured and the heat loss of the shaft kilometers corresponding to the actual daily production.
3. The method of claim 1 or 2, wherein obtaining the wellbore kilometer heat loss comprises:
and the bottom hole temperature of the condensate gas well is different from the wellhead temperature, and the ratio of the difference value to the well depth data is the heat loss of the well shaft kilometer.
4. A method according to claim 3, wherein the wellhead temperature is obtained by a temperature sensor mounted at the wellhead of the condensate well.
5. The method of claim 4, wherein the temperature sensor of the condensate well wellhead is located at the production wing of the christmas tree and at the outlet end of the nozzle tip.
6. The method of claim 1, wherein one of the gas and oil yields of the gas and oil well is obtained from the production of the gas and oil well, and the other of the gas and oil well is obtained from the calculation of the one of the gas and oil yields of the gas and oil well.
7. The method of claim 6, wherein obtaining one of the gas and oil yields of the gas and oil well to be measured from the production of the gas and oil well to be measured from the date of the gas and oil well to be measured, and calculating the other of the gas and oil yields of the gas and oil well to be measured from the date of the gas and oil well to be measured, comprises:
the yield of the condensate gas well on the date to be measured is the gas yield of the condensate gas well on the date to be measured, the gas-oil ratio of the condensate gas well is obtained, and the oil yield of the condensate gas well on the date to be measured is calculated according to the gas-oil ratio and the gas yield of the condensate gas well on the date to be measured.
8. The method of claim 6, wherein obtaining one of the gas and oil yields of the gas and oil well to be measured from the production of the gas and oil well to be measured from the date of the gas and oil well to be measured, and calculating the other of the gas and oil yields of the gas and oil well to be measured from the date of the gas and oil well to be measured, comprises:
the yield of the condensate gas well on the date to be measured is the oil yield of the condensate gas well on the date to be measured, the oil-gas ratio of the condensate gas well is obtained, and the gas yield of the condensate gas well on the date to be measured is calculated according to the oil-gas ratio and the oil yield of the condensate gas well on the date to be measured.
9. The method as recited in claim 1, further comprising:
fitting the actual daily production of the condensate gas well on the date to be measured and the corresponding kilometer heat loss of the shaft to the production prediction standard curve to update the production prediction standard curve.
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