CN-122021430-A - Method and device for calculating oil-gas two-phase flow output profile

CN122021430ACN 122021430 ACN122021430 ACN 122021430ACN-122021430-A

Abstract

The embodiment of the application discloses a method and a device for calculating an oil-gas two-phase flow output profile. The method comprises the steps of generating a geothermal gradient curve according to distributed temperature sensing logging data of a target logging, generating a pseudo pressure curve according to pressure data of the target logging, obtaining a PVT phase diagram of the target logging, generating a density profile curve of the target logging according to the geothermal gradient curve, the pseudo pressure curve and the PVT phase diagram, and calculating an oil-gas two-phase flow output profile according to the distributed temperature sensing logging data, the geothermal gradient curve and the density profile curve. By adopting the scheme, the calculation accuracy of the oil-gas two-phase flow output profile of the high-temperature high-pressure oil-gas reservoir can be improved.

Inventors

LI JILING
MENG LI
NIU PENG
LI NIANZE
DENG YANG
JIA CAIXIA
CHI JIAWEI

Assignees

中海油田服务股份有限公司

Dates

Publication Date: 20260512
Application Date: 20260128

Claims (10)

1. A method for calculating a production profile of an oil and gas two-phase flow, comprising: generating a ground temperature gradient curve according to the distributed temperature sensing logging data of the target logging; generating a pseudo pressure curve according to the pressure data of the target logging; Acquiring a PVT phase diagram of the target logging; Generating a density profile curve of the target logging according to the geothermal gradient curve, the quasi-pressure curve and the PVT phase diagram; And calculating an oil-gas two-phase flow output profile according to the distributed temperature sensing logging data, the geothermal gradient curve and the density profile curve.
2. The method of claim 1, wherein the generating the density profile curve of the target log from the geothermal gradient curve, the pseudopressure curve, and the PVT phase diagram comprises: determining a plurality of control points for any perforation interval; for any control point, determining the liquid phase content of the control point according to a ground temperature gradient curve, a quasi-pressure curve and a PVT phase state diagram; Calculating the density of the mixed fluid of any control point according to the liquid phase content of the control point and the physical property parameter of the target logging; and generating a density profile curve of the target well logging according to the mixed fluid density of each control point.
3. The method of claim 2, wherein the control points comprise a layer top control point and a layer bottom control point.
4. The method of claim 2, wherein determining the liquid phase content of the control point based on the geothermal gradient profile, the pseudopressure profile, and the PVT phase diagram comprises: inquiring the ground temperature gradient curve to obtain a temperature value of the control point according to the depth of the control point, and inquiring the quasi-pressure curve to obtain a pressure value of the control point; and inquiring the PVT phase diagram based on the temperature value and the pressure value of the control point to obtain the liquid phase content of the control point.
5. The method of any one of claims 1-4, wherein calculating an oil and gas two-phase flow production profile from the distributed temperature sensing log data, the geothermal gradient profile, and the density profile comprises: constructing a shaft-stratum coupling thermodynamic model based on the geothermal gradient curve and the density profile curve; According to the two-phase flow stratified flow value of the current iterative step, operating the shaft-stratum coupling thermodynamic model, and calculating an iterative error; if the iteration error meets the iteration ending condition, taking the two-phase flow stratified flow value of the current iteration step as an oil-gas two-phase flow output profile result; and if the iteration error meets the condition of no iteration end, updating the two-phase flow layering flow value, executing the two-phase flow layering flow value according to the current iteration step, operating the shaft-stratum coupling thermodynamic model, and calculating the iteration error.
6. The method of any one of claims 1-4, wherein the generating a geothermal gradient profile from the distributed temperature-sensing log data of the target log comprises: Acquiring a shut-in temperature curve and a well opening temperature curve of a target well logging; Identifying a zero-yield segment based on the open-well temperature profile; calculating an initial trend line according to the zero output section; and correcting the initial trend line by using the shut-in temperature curve to generate a ground temperature gradient curve.
7. An oil and gas two-phase flow output profile calculation device, comprising: The first processing module is used for generating a ground temperature gradient curve according to the distributed temperature sensing logging data of the target logging; generating a pseudo pressure curve according to the pressure data of the target logging; The second processing module is used for generating a density profile curve of the target logging according to the geothermal gradient curve, the quasi-pressure curve and the PVT phase diagram; And the profile calculation module is used for calculating the oil-gas two-phase flow output profile according to the distributed temperature sensing logging data, the geothermal gradient curve and the density profile curve.
8. A computing device comprising a processor, a memory, a communication interface, and a communication bus, the processor, the memory, and the communication interface completing communication with each other over the communication bus; the memory is configured to store at least one executable instruction that causes the processor to perform operations corresponding to the method for calculating a production profile of an oil and gas two-phase flow as set forth in any one of claims 1-6.
9. A computer storage medium having stored therein at least one executable instruction for causing a processor to perform operations corresponding to the method for calculating a production profile of an oil and gas two-phase flow as set forth in any one of claims 1-6.
10. A computer program product comprising at least one executable instruction that causes a processor to perform operations corresponding to the method of calculating a production profile of an oil and gas two-phase flow as set forth in any one of claims 1-6.

Description

Method and device for calculating oil-gas two-phase flow output profile Technical Field The embodiment of the application relates to the technical field of exploration, in particular to a method, a device, computing equipment, a computer storage medium and a computer program product for computing an oil-gas two-phase flow output profile. Background The oil-gas two-phase flow output profile is a comprehensive profile of the distribution characteristics of the output, physical properties, flow parameters and the like of the oil-gas two-phase flow along the well depth direction in a vertical shaft or a horizontal shaft section of an oil-gas well. The method reflects the oil production and gas production capacities of different layers of the oil reservoir and the flow state of fluid in a shaft, and is a core basis for analyzing the oil reservoir utilization degree, making measures such as profile control and water shutoff or layer mining. A high temperature high pressure hydrocarbon reservoir is a special hydrocarbon reservoir where the formation temperature and formation pressure are significantly higher than conventional hydrocarbon reservoirs. Distributed temperature sensing (Distributed Temperature Sensing, DTS for short) optical fiber logging is widely applied to high-temperature high-pressure oil-gas reservoir logging by the characteristics of high-temperature resistance, high-pressure resistance, electromagnetic resistance, radio interference resistance and the like. However, the inventor finds that in the implementation process, in the prior art, in the logging of a high-temperature high-pressure oil-gas reservoir, the calculation precision of the oil-gas two-phase flow output profile obtained only according to a temperature curve obtained by the distributed temperature sensing optical fiber logging and the data of the pressure gauge is insufficient. Disclosure of Invention The present application has been developed in response to the above-discussed problems, and in order to provide a method, apparatus, computing device, computer storage medium, and computer program product for calculating an oil and gas two-phase flow production profile that overcomes, or at least partially solves, the above-discussed problems. According to a first aspect of the present application, there is provided a method for calculating a production profile of an oil and gas two-phase flow, comprising: generating a ground temperature gradient curve according to the distributed temperature sensing logging data of the target logging; generating a pseudo pressure curve according to the pressure data of the target logging; Acquiring a PVT phase diagram of the target logging; Generating a density profile curve of the target logging according to the geothermal gradient curve, the quasi-pressure curve and the PVT phase diagram; And calculating an oil-gas two-phase flow output profile according to the distributed temperature sensing logging data, the geothermal gradient curve and the density profile curve. In an alternative embodiment, the generating the density profile curve of the target log from the geothermal gradient curve, the pseudo pressure curve, and the PVT phase diagram includes: determining a plurality of control points for any perforation interval; for any control point, determining the liquid phase content of the control point according to a ground temperature gradient curve, a quasi-pressure curve and a PVT phase state diagram; Calculating the density of the mixed fluid of any control point according to the liquid phase content of the control point and the physical property parameter of the target logging; and generating a density profile curve of the target well logging according to the mixed fluid density of each control point. In an alternative embodiment, the control points include a layer top control point and a layer bottom control point. In an alternative embodiment, the determining the liquid phase content of the control point according to the geothermal gradient curve, the pseudo-pressure curve and the PVT phase diagram includes: inquiring the ground temperature gradient curve to obtain a temperature value of the control point according to the depth of the control point, and inquiring the quasi-pressure curve to obtain a pressure value of the control point; and inquiring the PVT phase diagram based on the temperature value and the pressure value of the control point to obtain the liquid phase content of the control point. In an alternative embodiment, the calculating the oil and gas two-phase flow production profile from the distributed temperature sensing log data, the geothermal gradient profile, and the density profile comprises: constructing a shaft-stratum coupling thermodynamic model based on the geothermal gradient curve and the density profile curve; According to the two-phase flow stratified flow value of the current iterative step, operating the shaft-stratum coupling thermodynamic model, and calculating