Annular fluid sampling and detecting system and method for high-temperature and high-pressure gas well

Abstract

The invention discloses an annulus fluid sampling and detecting system and method for a high-temperature and high-pressure gas well, the system comprises a sampling pressure reduction module, a gas-liquid separation module, a component analysis module and a data acquisition module, the sampling pressure reduction module is adopted to carry out pressure reduction sampling on an annulus fluid, sampling of the annulus fluid in a high-pressure environment is achieved, and the sampling efficiency is improved. The gas-liquid separation module is used for carrying out gas-liquid separation on the annulus fluid, and the data acquisition module is used for acquiring sampling data before and after the gas-liquid separation and the component analysis module is used for analyzing and collecting the data. The component analysis module comprises a gas phase analysis unit and a liquid phase analysis unit and can realize fluid component analysis and ion component analysis, the gas phase analysis unit comprises a gas chromatograph and a hydrogen sulfide analyzer, and the liquid phase analysis unit comprises an ion chromatograph and a liquid chromatograph.

Description

Technical Field

[0001] The present invention relates to the field of annular fluid technology, and in particular to an annular fluid sampling and detection system and method for high-temperature and high-pressure gas wells. Background Art

[0002] At present, foreign countries have carried out certain research on the annulus pressure problem. A complete set of monitoring systems for oil and gas wells with annulus pressure has been formed. A company has developed an annulus pressure monitoring system for oil and gas wells, which can monitor the annulus gas leakage and the annulus liquid level position.

[0003] The annulus pressure monitoring system developed by the company collects information including detailed well information, well production data, corrosion data, well annulus pressure values, leakage rate measurement, fluid analysis, and conducts annulus pressure risk assessment and classification for annulus pressure oil and gas wells.

[0004] There is also an annulus pressure monitoring system to monitor the annulus pressure and annulus gas composition to assist in the safe management of annulus pressure gas wells.

[0005] There is also a ground pressure monitoring automatic recorder, the main function of which is to automatically record the changes in the wellhead annulus pressure, thereby providing real-time pressure data for the annulus pressure control test and providing technical support for on-site annulus pressurization, constant pressure and pressure relief operations.

[0006] A company has developed an on-site gas seal detection system for wellhead equipment and developed on-site detection and diagnosis technology for wellhead equipment. The detection system monitors the sealing status of wellhead equipment in real time by outputting 140MPa water pressure or high-pressure nitrogen, and detects leaks in wellhead equipment through acoustic emission technology.

[0007] The company has also developed an annular pressure monitoring system while drilling. The system consists of a wireless measurement while drilling tool and an annular pressure measurement while drilling tool. It can measure the pressure and temperature data of the annular bottom and transmit it to the ground in real time, so as to accurately understand the changes in bottom hole temperature and pressure, improve the control accuracy of pressure-controlled drilling and deep underbalanced well drilling, and provide technical support for field operations.

[0008] The company has also developed a downhole liquid level monitoring system, which can continuously measure the liquid level position in the annulus and derive the leakage rate of the well-killing fluid based on the liquid level depth in the annulus, providing a basis for reasonably determining the amount of well-killing fluid to be injected during drilling.

[0009] A company has developed an annular pressure well diagnosis and detection technology to address the dangerous situation of annular pressure caused by leakage of offshore oil and gas production pipes. A ground positioning model for downhole pipe leakage based on wellbore pressure distribution was established. A ground detection and diagnosis system for annular pressure suitable for offshore production platforms was developed, which integrates monitoring indicators such as pressure, flow, temperature, liquid level and gas composition. For an offshore production platform, the system successfully diagnosed the pressure source and leakage location of the annular pressure gas well.

[0010] A certain company has developed an annulus pressure testing and diagnosis system for high-temperature, high-pressure, high-sulfur well conditions and annulus pressure diagnosis and testing requirements. The system has functions such as real-time storage and transmission of high-precision pressure (0.01MPa), annulus air quality component analysis, annulus fluid pH value analysis, and automatic ignition of pressure relief, realizing rapid diagnosis and analysis of wells with abnormal annulus pressure.

[0011] However, the pressure level temperature and functional fluid analysis performance of the existing oil and gas well annulus pressure diagnosis system cannot meet the conditions of higher temperature and pressure. The existing equipment has a low safety factor under high temperature and pressure conditions and is difficult to use. In addition, the existing system can only perform a simple analysis of the fluid components, without analysis of the fluid components (organic matter in the liquid) and ion components (including Cl-, Ca2+, Mg2+, Ba2+, +Sr2+, Na+, K+, Cr2+, Fe ions, etc. and other metal ions of casing corrosion). Summary of the invention

[0012] The purpose of the present invention is to provide an annulus fluid sampling and detection system and method for high-temperature and high-pressure gas wells, so as to overcome the problem that the existing systems in the prior art can only perform simple analysis of fluid components but not analysis of fluid components and ion components.

[0013] To achieve the above object, the present invention provides the following technical solutions:

[0014] An annular fluid sampling and detection system for high-temperature and high-pressure gas wells, comprising a sampling and decompression module, a gas-liquid separation module, a component analysis module and a data acquisition module;

[0015] The sampling and decompression module is used to decompress and sample the annular fluid, transmit the sampled annular fluid to the gas-liquid separation module, perform data measurement, and transmit the measured data to the data acquisition module;

[0016] The gas-liquid separation module is used to perform gas-liquid separation on the sampled annular fluid to obtain the separated annular fluid, transmit the separated annular fluid to the component analysis module, perform data measurement on the annular fluid after gas-liquid separation, and transmit the measured data to the data acquisition module;

[0017] The component analysis module is used to perform gas-liquid phase analysis on the gas phase and liquid phase fluids in the gas-liquid separation module, and send the analysis results to the data acquisition module;

[0018] The data acquisition module is used to receive the annular space fluid data before decompression, the annular space fluid data measured by the sampling decompression module, the annular space fluid data measured by the gas-liquid separation module and the component analysis module data.

[0019] Preferably, the sampling decompression module comprises a collection unit, a primary decompression unit and a secondary decompression unit which are connected in sequence.

[0020] Preferably, the first-stage pressure reducing unit is two pipelines connected in parallel, one of which is a pressure reducing pipeline and the other is a normal pipeline, and the two pipelines are not opened at the same time.

[0021] Preferably, the gas-liquid separation module includes a gas-liquid separation unit, a liquid phase unit and a gas phase unit. The gas-liquid separation unit is used to perform gas-liquid separation of the annulus fluid. The liquid phase unit and the gas phase unit are respectively connected to both sides of the gas-liquid separation unit to collect liquid phase data and gas phase data of the annulus fluid respectively.

[0022] Preferably, the data acquisition module includes a data collector, a signal converter, a data analyzer, a signal transmitter and a display which are connected in sequence.

[0023] Preferably, the component analysis module includes a gas phase analysis unit and a liquid phase analysis unit.

[0024] Preferably, the gas phase analysis unit includes a gas chromatograph and a hydrogen sulfide analyzer.

[0025] Preferably, the liquid phase analysis unit comprises an ion chromatograph and a liquid chromatograph.

[0026] Preferably, the sampling decompression module is arranged inside the explosion-proof box and is used to be connected to the wellhead annulus.

[0027] A method for sampling and detecting annular fluid in a high-temperature and high-pressure gas well, comprising:

[0028] Acquire the annular fluid, decompress the annular fluid to obtain the decompressed annular fluid, and collect data on the decompressed annular fluid to obtain the decompressed annular fluid data;

[0029] Performing gas-liquid separation on the annular fluid after decompression to obtain separated annular fluid, and performing data measurement on the sampled material after gas-liquid separation to obtain separated annular fluid data;

[0030] Perform component analysis on the gas phase and liquid phase after gas-liquid separation to obtain component analysis data;

[0031] Collect annular fluid data before and after decompression, annular fluid data after gas-liquid separation, and component analysis data.

[0032] Compared with the prior art, the present invention has the following beneficial effects: the present invention provides an annulus fluid sampling and detection system for high-temperature and high-pressure gas wells, including a sampling decompression module, which is used to decompress and sample the annulus fluid, thereby realizing the sampling of the annulus fluid under a high-pressure environment, and then using a gas-liquid separation module to separate the gas and liquid in the annulus fluid, performing component analysis through a component analysis module, and collecting data before and after gas-liquid separation and analyzing data through a data acquisition module;

[0033] Furthermore, the component analysis module includes a gas phase analysis unit and a liquid phase analysis unit, which can realize fluid component analysis and ion component analysis. BRIEF DESCRIPTION OF THE DRAWINGS

[0034] Figure 1 A block diagram of an annular fluid sampling and detection system for high temperature and high pressure gas wells;

[0035] Figure 2 A flow chart of an annular fluid sampling and detection method for high temperature and high pressure gas wells;

[0036] Figure 3 A connection diagram of an annular fluid sampling and detection system for high-temperature and high-pressure gas wells;

[0037] In the figure, 1-first manual needle valve, 2-second manual needle valve, 3-high-pressure safety valve, 4-first pressure sensor, 5-high-pressure filter, 6-electric ball valve, 7-first temperature sensor, 8-third manual needle valve, 9-flow sensor, 10-fourth manual needle valve, 11-fifth manual needle valve, 12-first pressure reducing valve, 13-first safety valve, 14-second pressure sensor, 15-first electric heater, 16-first check valve, 17-sixth manual needle valve, 18-secondary pressure reducing valve, 19-second safety valve, 20- The seventh manual needle valve, 21-the third pressure sensor, 22-the secondary electric heater, 23-the second temperature sensor, 24-the electric ball valve, 25-the eighth manual needle valve, 26-the low pressure filter, 27-the liquid level controller, 28-the gas-liquid separator, 29-the liquid phase flow sensor, 30-the liquid phase pipeline safety valve, 31-the first liquid phase pipeline manual needle valve, 32-the liquid phase solenoid valve, 33-the liquid level controller, 34-the waste liquid storage tank, 35-the fourth pressure sensor, 36-the fifth pressure sensor, 37-the first liquid phase solenoid valve, 3 8-second liquid phase solenoid valve, 39-second liquid phase pipeline manual needle valve, 40-third liquid phase pipeline manual needle valve, 41-fourth liquid phase pipeline manual needle valve, 42-fifth liquid phase pipeline manual needle valve, 43-sixth gas phase pipeline manual needle valve, 44-gas phase flow sensor, 45-gas phase pressure sensor, 46-first gas phase solenoid valve, 47-first gas phase pipeline manual needle valve, 48-second gas phase pipeline manual needle valve, 49-third gas phase pipeline manual needle valve, 50-fourth gas phase pipeline manual needle valve, 51-gas phase pipeline safety valve, 5 2-the second gas phase solenoid valve, 53-vacuum pump, 54-waste gas buffer tank, 55-vent tank, 56-the first vent pipeline manual needle valve, 57-the second one-way valve, 58-pressure reducing valve, 59-the second vent pipeline manual needle valve, 60-the third vent pipeline manual needle valve, 61-PH monitor, 62-gas chromatograph, 63-ion chromatograph, 64-liquid chromatograph, 65-hydrogen sulfide analyzer, 66-data acquisition device, 67-signal converter, 68-data analyzer, 69-signal remote transmitter, 70 monitoring display. DETAILED DESCRIPTION

[0038] In order to make the purpose, 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 in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are part of the embodiments of the present invention, not all of the embodiments. Generally, the components of the embodiments of the present invention described and shown in the drawings here can be arranged and designed in various different configurations.

[0039] Therefore, the following detailed description of the embodiments of the present invention provided in the accompanying drawings is not intended to limit the scope of the invention claimed for protection, but merely represents selected embodiments of the present invention. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of the present invention.

[0040] It should be noted that similar reference numerals and letters denote similar items in the following drawings, and therefore, once an item is defined in one drawing, further definition and explanation thereof is not required in subsequent drawings.

[0041] In the description of the embodiments of the present invention, it should be noted that if the terms "upper", "lower", "horizontal", "inner", etc. indicate an orientation or positional relationship based on the orientation or positional relationship shown in the drawings, or the orientation or positional relationship in which the product of the invention is usually placed when in use, it is only for the convenience of describing the present invention and simplifying the description, and does not indicate or imply that the device or element referred to must have a specific orientation, be constructed and operated in a specific orientation, and therefore cannot be understood as a limitation on the present invention. In addition, the terms "first", "second", etc. are only used to distinguish the description, and cannot be understood as indicating or implying relative importance.

[0042] In addition, if the term "horizontal" appears, it does not mean that the component must be absolutely horizontal, but can be slightly tilted. For example, "horizontal" only means that its direction is more horizontal than "vertical", which does not mean that the structure must be completely horizontal, but can be slightly tilted.

[0043] In the description of the embodiments of the present invention, it is also necessary to explain that, unless otherwise clearly specified and limited, the terms "set", "install", "connect", and "connect" should be understood in a broad sense, for example, it can be a fixed connection, a detachable connection, or an integral connection; it can be a mechanical connection or an electrical connection; it can be a direct connection, or it can be indirectly connected through an intermediate medium, or it can be the internal connection of two components. For ordinary technicians in this field, the specific meanings of the above terms in the present invention can be understood according to specific circumstances.

[0044] The present invention is further described in detail below in conjunction with the accompanying drawings:

[0045] like Figure 1 As shown, the present invention provides an annulus fluid sampling and detection system for high-temperature and high-pressure gas wells, including a sampling and decompression module, a gas-liquid separation module, a data acquisition module and a component analysis module;

[0046] The sampling and decompression module is used to decompress and sample the annular fluid, transmit the sampled annular fluid to the gas-liquid separation module, perform data measurement, and transmit the measured data to the data acquisition module;

[0047] The gas-liquid separation module is used to perform gas-liquid separation on the sampled annular fluid to obtain the separated annular fluid, transmit the separated annular fluid to the component analysis module, perform data measurement on the annular fluid after gas-liquid separation, and transmit the measured data to the data acquisition module;

[0048] The component analysis module is used to perform gas-phase and liquid-phase analysis on the gas-phase and liquid-phase annular space fluids in the gas-liquid separation module, and send the analysis results to the data acquisition module;

[0049] The data acquisition module is used to receive the annular space output data measured by the sampling and decompression module before and after gas-liquid separation, the annular space fluid data measured by the gas-liquid separation module, and the component analysis module analyzed by the analysis module.

[0050] The sampling decompression module comprises a collection unit, a primary decompression unit and a secondary decompression unit which are connected in sequence.

[0051] The first-level pressure reducing unit is two pipelines connected in parallel, one of which is a pressure reducing pipeline and the other is a normal pipeline, and the two pipelines are not opened at the same time.

[0052] The gas-liquid separation module includes a gas-liquid separation unit, a liquid phase unit and a gas phase unit. The gas-liquid separation unit is used to perform gas-liquid separation of annular fluid. The liquid phase unit and the gas phase unit are respectively connected to both sides of the gas-liquid separation unit to collect liquid phase data and gas phase data of the annular fluid respectively.

[0053] The data acquisition module includes a data collector, a signal converter, a data analyzer, a signal transmitter and a display connected in sequence. The data analyzer transmits the analyzed data to the component analysis module for further analysis.

[0054] The component analysis module includes a gas phase analysis unit and a liquid phase analysis unit.

[0055] The gas phase analysis unit includes a gas chromatograph and a hydrogen sulfide analyzer.

[0056] The liquid phase analysis unit includes an ion chromatograph and a liquid chromatograph.

[0057] The sampling decompression module is arranged inside the explosion-proof box and is used for connecting with the wellhead annulus.

[0058] like Figure 2 As shown, the present invention also provides an annulus fluid sampling and detection method for a high-temperature and high-pressure gas well, comprising:

[0059] S101 acquires the annular fluid, decompresses the annular fluid, obtains the decompressed annular fluid, and collects data of the decompressed annular fluid to obtain the decompressed annular fluid data;

[0060] S102 performs gas-liquid separation on the annular fluid after decompression to obtain separated annular fluid, and performs data measurement on the sampled material after gas-liquid separation to obtain separated annular fluid data;

[0061] S103 analyzes the gas phase and liquid phase of the separated annular fluid data to obtain analysis results;

[0062] S104 collects the annular fluid data before and after decompression, the annular fluid data after separation and the analysis results.

[0063] Example:

[0064] The oil and gas well pressure sampling and analysis system consists of four parts: annulus high-pressure sampling, gas-liquid separation, component analysis and data processing, all of which are automatically controlled.

[0065] (1) The high-pressure sampling pressure reducing part is composed of the high-pressure first manual needle valve 1 of the venting interface, the high-pressure second manual needle valve 2 of the sampling pipeline, the 120MPa high-pressure safety valve 3, the first pressure sensor 4, the high-pressure filter 5, the high-pressure electric ball valve 6, the first temperature sensor 7, the third manual needle valve 8 of the pressure test interface, the flow sensor 9, the fourth manual needle valve 10 of the high-pressure, the fifth manual needle valve 11 of the first-level pressure reducing valve crossing pipeline, the first-level pressure reducing valve 12, the 41MPa safety valve 13, the pressure sensor 14, the first-level electric heater 15, the check valve 16, the check valve 57, the manual needle valve 17 of the venting pipeline, the second-level pressure reducing valve 18, the 1MPa second safety valve 19, the seventh manual needle valve 20 of the venting pipeline, the third pressure sensor 21, the second-level electric heater 22, the second temperature sensor 23, etc. All the components are installed in an explosion-proof box for connecting with the wellhead annulus.

[0066] The high-pressure filter has a filtration accuracy of 56μm, an operating temperature of -20℃~200℃, and a pressure resistance of 20000psi; the first-stage pressure reducing valve has a maximum wellhead pressure of 20000psi, and an outlet pressure of 50~6000psi is adjustable; the second-stage pressure reducing valve has a maximum inlet pressure of 6000psi, and an outlet pressure of 10~200psi is adjustable. The connection method of the pressure reducing valve is 3 / 8in NPT buckle type.

[0067] Connection position: ("KQ103 / 78-140FF-NL Production (Oil) Gas Wellhead Ordering Technical Requirements" and field survey data) The connection position connects to the HF9 9 / 16"-30000psi-F buckle type interface on the instrument flange marked 12 in the production (oil) gas tree diagram or the 1 / 2" NPT buckle type interface on the plug marked 4.

[0068] (2) The gas-liquid separation module is designed to withstand a pressure of 16MPa and an operating pressure of less than 1MPa. It consists of a high-pressure electric ball valve 24, a high-pressure eighth manual needle valve 25, a low-pressure filter 26, a gas-liquid separator level controller 27, a 20L gas-liquid separator 28, a liquid phase flow sensor 29, a pH value detector 61, a 1MPa liquid phase safety valve 30, a first liquid phase pipeline manual needle valve 31, a liquid phase solenoid valve 32, a liquid level controller 33, and a 100L waste liquid storage tank 34; a sixth gas phase output manual needle valve 43, a gas phase flow sensor 44, a gas phase pipeline safety valve 51, a second gas phase solenoid valve 52, a vacuum pump 53, and a 30L waste gas buffer tank 54. The low-pressure filter has a filtration accuracy of 10μm, an operating temperature of -20℃ to 200℃, and a pressure resistance of 6000psi.

[0069] The gas-liquid separation part adopts two-stage separation. In the first-stage cyclone separation, the cyclone separator has a free gas phase and liquid phase separation rate of 90%; in order to ensure that the liquid phase in the gas phase is as small as possible, the cyclone separation gas enters the second-stage filtration separation section for further separation, and the filtration separation free gas phase and liquid phase separation rate is 95%; the overall free gas phase and liquid phase separation rate reaches 98%, and the gas phase and liquid phase after separation enter the component testing system respectively.

[0070] (3) Component analysis

[0071] The liquid phase analysis module is used to analyze specific components in the liquid phase, which is divided into ion chromatography analysis and liquid chromatography analysis.

[0072] Liquid phase analysis is divided into two routes, one route is composed of the fourth pressure sensor 35, the first liquid phase solenoid valve 37, the second liquid phase pipeline manual needle valve 39, the liquid chromatograph 64, and the fourth liquid phase pipeline manual needle valve 41; the other route is composed of the fifth pressure sensor 36, the second liquid phase solenoid valve 38, the ion chromatograph 63, and the fifth liquid phase pipeline manual needle valve 42. The above solenoid valves are used for emergency cutoff, and the manual needle valves are used for normal test analysis and adjustment.

[0073] The gas phase analysis module is used to analyze the gas phase components of the output, and is composed of a gas chromatograph and a hydrogen sulfide analyzer. Since hydrogen sulfide is an interfering gas component in the chromatographic column, it is analyzed separately.

[0074] The gas phase analysis module is also implemented in two ways, consisting of a gas phase pressure sensor 45 and a first gas phase solenoid valve 46; the first gas phase solenoid valve 46 is divided into two ways, one way is connected to the gas chromatograph 62 and the third gas phase pipeline manual needle valve 49 through the first gas phase pipeline manual needle valve 47, and the other way is connected to the hydrogen sulfide analyzer 65 and the fourth gas phase pipeline manual needle valve 50 through the second gas phase pipeline manual needle valve 48. The electromagnetic ball valve is used for quick cut-off, and the manual needle valve is used for test analysis and adjustment.

[0075] (4) Online flow measurement

[0076] Test pressure, flow and temperature online. The high-pressure sampling module is equipped with a first pressure sensor 4, a first temperature sensor 7, a flow sensor 9, a second pressure sensor 14 after the first-stage decompression, a third pressure sensor 21 after the second-stage decompression and a second temperature sensor 23; the gas-liquid separation module is equipped with a gas phase flow sensor 44, a gas phase pressure sensor 45, a liquid phase flow sensor 29, a fourth pressure sensor 35 and a fifth pressure sensor 36. There are 11 monitoring points in total.

[0077] The separated gas phase and liquid phase are measured again for flow rate, and the data are transmitted to the data acquisition device. The total amount is based on the measurement of the flow sensor 9, and the gas phase pressure sensor 45 and the liquid phase flow sensor 29 measure the data to obtain the gas-liquid ratio of the corresponding period.

[0078] The electric control points are: high-pressure electric ball valve 6, primary electric heater 15, secondary electric heater 22, high-pressure electric ball valve 24, gas-liquid separator level controller 27, liquid phase solenoid valve 32, waste liquid storage tank level controller 33, first liquid phase solenoid valve 37, second liquid phase solenoid valve 38, first gas phase solenoid valve 46, second gas phase solenoid valve 52, vacuum pump 53. A total of 12 control points.

[0079] (5) Data acquisition consists of a data acquisition device 66, a signal converter 67, a data analyzer 68, a signal remote transmitter 69 and a monitoring display 70, which are centrally installed on a mobile skid. The flow rate, pressure, and temperature data of the online sampling main line test and the flow rate, pressure, and temperature data of each branch line test after gas-liquid separation are uniformly transmitted to the data acquisition equipment, and then centralized to the control computer, combined with the gas-liquid chromatograph analysis data, and analyzed by the analysis software to obtain the test analysis results.

[0080] The present invention is mainly used for testing and analyzing the production parameters and discharges of the annulus of oil and gas wells. The specific use method is as follows:

[0081] (1) The equipment enters the well site to be tested and is placed in place according to the design;

[0082] (2) Connect the valve outlets at the annular output end corresponding to the three outlet pipelines of the equipment, and check that all valves in the system are in the closed position;

[0083] (3) Start the generator, turn on the power, start the control computer and data acquisition assembly to check the performance parameters of each part;

[0084] (4) Open the high-pressure solid-liquid separator drain valve, separator liquid phase output main pipe gate valve, ion chromatograph liquid supply control valve, liquid chromatograph liquid supply control valve, separator gas phase outlet control valve, separator gas phase outlet throttle valve, and gas chromatograph gas supply control valve in sequence, continuously inject standard cleaning solution from the drain pipeline, start the ion chromatograph, liquid chromatograph, and gas chromatograph for continuous monitoring, and stop cleaning when the substance components monitored by the three sets of chromatographs are the same as those of the standard cleaning solution.

[0085] (5) Remove the cleaning liquid injection equipment, drain the cleaning liquid in the system, close the high-pressure solid-liquid separator drain valve, and close all valves in the system.

[0086] (6) Start testing the discharge, pressure, temperature and flow rate of annulus A.

[0087] (7) Open the wellhead A annulus output valve, the A annulus pipeline flat gate valve, the A annulus pipeline throttle valve, the sampling main line gate valve, the separator liquid phase output main pipe gate valve, the ion chromatography liquid supply control valve, the liquid chromatography liquid supply control valve, the separator gas phase outlet control valve, the separator gas phase outlet throttle valve, and the gas chromatography gas supply control valve in sequence.

[0088] (8) Start the ion chromatograph, liquid chromatograph, and gas chromatograph to conduct continuous analysis, and transmit the analysis data to the control computer.

[0089] (9) When the three sets of chromatographs show that the analysis results do not contain the standard cleaning solution components, the formal testing phase begins and the analysis software assembly is started for continuous analysis.

[0090] (10) The formal test of the discharge, pressure, temperature and flow of annulus A is carried out for 30 minutes, and the output valve of annulus A at the wellhead is closed to stop the fluid supply.

[0091] (11) The three chromatographs are shut down according to their respective delay times.

[0092] (12) Open the high-pressure solid-liquid separator drain valve to drain the substances in the system.

[0093] (13) The A annulus test is completed.

[0094] (14) Repeat steps (4) to (12) to test annulus B.

[0095] (15) Repeat steps (4) to (12) to test the C annulus.

[0096] (16) The test is completed.

[0097] (17) Open the high-pressure solid-liquid separator drain valve to drain the substances in the system.

[0098] (18) Remove the three annular connection pipelines of the well control.

[0099] (19) Repeat steps (4) and (5) to clean the test system.

[0100] (20) Turn off the generator, clean up the work site, and organize the test tools.

[0101] (21) The on-site operations manager, operations supervisor, and well site management personnel confirm the completion of the operations and sign.

[0102] (22) Operating equipment and personnel are evacuated from the site.

[0103] (23) Organize work reports and keep them on file.

[0104] (24) The job is completed.

[0105] like Figure 3 As shown, the installation method of the sampling pressure reduction module

[0106] The high-pressure sampling port is connected to the HF9 9 / 16″-30000psi-F buckle interface on the instrument flange of the annulus or the 1 / 2″NPT buckle interface on the plug with a threaded high-pressure hose that can withstand a pressure of 30,000psi.

[0107] The liquid inlet pipe uses a 80-grade 3 / 8in×0.065in2205 stainless steel capillary tube to be connected to the venting high-pressure first manual needle valve 1 through a tee. The outlet of the high-pressure first manual needle valve 1 is connected to the spray pipe line; the other outlet of the tee is connected to the inlet of the high-pressure second manual needle valve;

[0108] The outlet of the second high-pressure manual needle valve is connected to the inlet of the 120MPa high-pressure safety valve 3 with a HF9 9 / 16″-30000psi-F buckle type;

[0109] The outlet of the 120MPa high-pressure safety valve 3 is connected to the inlet of the first pressure sensor 4 using a HF9 9 / 16″-30000psi-F buckle type;

[0110] The outlet of the first pressure sensor 4 is connected to the inlet of the high pressure filter 5 by using a HF9 9 / 16″-30000psi-F buckle type;

[0111] The outlet of the high-pressure filter 5 is connected to the inlet of the high-pressure electric ball valve 6 with a HF9 9 / 16″-30000psi-F buckle type;

[0112] The outlet of the high-pressure electric ball valve 6 is connected to the inlet of the first temperature sensor 7 by a HF9 9 / 16″-30000psi-F buckle type;

[0113] The outlet of the first temperature sensor 7 is connected to the inlet of the third manual needle valve 8 of the pressure test interface through a three-way outlet using HF9 9 / 16″-30000psi-F buckle type;

[0114] The outlet of the third manual needle valve 8 of the pressure test interface is connected to the pressure test equipment;

[0115] The other outlet of the tee is connected to the inlet of the flow sensor 9 by using a HF9 9 / 16″-30000psi-F buckle type, and the outlet of the flow sensor 9 is connected to the inlet of the high-pressure fourth manual needle valve 10 by using a HF9 9 / 16″-30000psi-F buckle type;

[0116] The outlet of the high-pressure fourth manual needle valve 10 is connected to a tee with a HF9 9 / 16″-30000psi-F buckle type, one outlet of the tee is connected to the inlet of the high-pressure fifth manual needle valve 11 of the crossing pipeline of the first-stage pressure reducing valve 12, and the outlet of the high-pressure fifth manual needle valve 11 is connected to the inlet of the second check valve 57 with a HF9 9 / 16″-30000psi-F buckle type;

[0117] The other outlet of the tee is connected to the inlet of the first-stage pressure reducing valve 12 with a HF9 9 / 16"-30000psi-F buckle type; the outlet of the first-stage pressure reducing valve 12 is connected to the inlet of the 41MPa first safety valve 13 with a HF9 9 / 16"-30000psi-F buckle type; the outlet of the 41MPa first safety valve 13 is connected to the inlet of the second pressure sensor 14 with a HF9 9 / 16"-30000psi-F buckle type; the outlet of the second pressure sensor 14 is connected to the inlet of the first-stage electric heater 15 with a HF9 9 / 16"-30000psi-F buckle type, and the outlet of the first-stage electric heater 15 is connected to the inlet of the first check valve 16 with a HF9 9 / 16"-30000psi-F buckle type;

[0118] The outlet of the first check valve 16 and the outlet of the second check valve 57 are connected to two ports of the same four-way valve by using HF9 9 / 16″-30000psi-F buckle type, and the other port of the four-way valve is connected to the venting sixth manual needle valve 17 by using HF9 9 / 16″-30000psi-F buckle type;

[0119] The fourth port of the four-way valve is connected to the inlet of the secondary pressure reducing valve 18 with a HF9 9 / 16″-30000psi-F buckle; the outlet of the secondary pressure reducing valve 18 is connected to the inlet of the 1MPa second safety valve 19 with a HF9 9 / 16″-30000psi-F buckle; the outlet of the 1MPa second safety valve 19 is connected to one port of the three-way valve with a HF9 9 / 16″-30000psi-F buckle, and the second outlet of the three-way valve is connected to the inlet of the seventh manual needle valve 20 of the venting pipeline with a HF9 9 / 16″-30000psi-F buckle;

[0120] The third port of the tee is connected to the inlet of the pressure sensor 21 with a HF9 9 / 16″-30000psi-F buckle; the outlet of the third pressure sensor 21 is connected to the inlet of the secondary electric heater 22 with a HF9 9 / 16″-30000psi-F buckle; the outlet of the secondary electric heater 22 is connected to the inlet of the second temperature sensor 23 with a HF9 9 / 16″-30000psi-F buckle; the outlet of the second temperature sensor 23 is connected to the inlet of the gas-liquid separator high-pressure electric ball valve 24 with a HF9 9 / 16″-30000psi-F buckle.

[0121] The gas-liquid separation module is designed to withstand a pressure of 16MPa, and the operating pressure is less than 1MPa. The installation method is as follows:

[0122] The inlet of the high-pressure electric ball valve 24 is connected to the outlet of the high-pressure sampling part; the outlet of the high-pressure electric ball valve 24 is connected to the inlet of the high-pressure eighth manual needle valve 25 by using a HF9 9 / 16″-30000psi-F buckle type;

[0123] The outlet of the high-pressure eighth manual needle valve 25 is connected to the inlet of the low-pressure filter 26 with a HF9 9 / 16″-30000psi-F buckle type; the outlet of the low-pressure filter 26 is connected to the liquid inlet pipeline of the 20L gas-liquid separator 28; the gas-liquid separator liquid level controller 27 is installed 300mm below; the liquid phase outlet of the gas-liquid separator 28 is located at the bottom, and the liquid phase flow sensor 29 is installed on the liquid phase outlet pipeline;

[0124] The outlet of the liquid phase flow sensor 29 is connected to the inlet of the pH value detector 61 by a ferrule joint; the outlet of the pH value detector 61 is connected to the first channel of the four-way by a ferrule, and the second channel of the four-way is connected to the 1MPa liquid phase safety valve 30 by a ferrule;

[0125] The outlet of the 1MPa liquid phase safety valve 30 is connected to the inlet of the liquid level control 33 of the 100L waste liquid storage tank by a pipeline; the third channel of the four-way is connected to the inlet of the first liquid phase pipeline manual needle valve 31 by a ferrule, the outlet of the first liquid phase pipeline manual needle valve 31 is connected to the inlet of the liquid phase solenoid valve 32 by a ferrule, and the outlet of the liquid phase solenoid valve 32 is connected to another inlet of the 100L waste liquid storage tank 33 by a pipeline; the fourth channel of the four-way is connected to the inlet of a three-way by a ferrule; the first outlet of the three-way is connected to the inlet of the fourth pressure sensor 35 by a ferrule, and the outlet of the fourth pressure sensor 35 is connected to the inlet of the fourth pressure sensor 35 by a ferrule. The ferrule is connected to the inlet of the first liquid phase solenoid valve 37; the outlet of the first liquid phase solenoid valve 37 is connected to the inlet of the second liquid phase pipeline manual needle valve 39 by a ferrule, and the outlet of the second liquid phase pipeline manual needle valve 39 is connected to the liquid chromatography sampling container; the second outlet of the three-way valve is connected to the inlet of the fifth pressure sensor 36 by a ferrule, and the outlet of the fifth pressure sensor 36 is connected to the inlet of the second liquid phase solenoid valve 38 by a ferrule; the outlet of the second liquid phase solenoid valve 38 is connected to the inlet of the fourth liquid phase pipeline manual needle valve 41 by a ferrule, and the outlet of the fourth liquid phase pipeline manual needle valve is connected to the ion chromatography sampling container.

[0126] The above solenoid valves are used for emergency cutoff, and the manual needle valves are used for normal testing, analysis and adjustment. The gas phase outlet of the 100L waste liquid storage tank 33 is located at the top, and the gas phase outlet pipeline is connected to a three-way inlet with a ferrule, and the first outlet of the tee is connected to the inlet of the gas phase pipeline safety valve 51 with a ferrule, and the outlet of the gas phase pipeline safety valve 51 is connected to the waste gas buffer tank 54 with a pipeline; the second outlet of the tee is connected to the inlet of the sixth gas phase pipeline manual needle valve 43 with a ferrule; the outlet of the sixth gas phase pipeline manual needle valve manual needle valve 43 is connected to the inlet of the gas phase flow sensor 44 with a ferrule, and the outlet of the gas phase flow sensor 44 is connected to a tee with a ferrule, and the first outlet of the tee is connected to the inlet of the second gas phase solenoid valve 52 with a ferrule, and the outlet of the second gas phase solenoid valve 52 is connected to the inlet of the vacuum pump 53 with a ferrule;

[0127] The outlet of the vacuum pump 53 is connected to the inlet of the exhaust gas buffer tank 54 by a pipeline; the second outlet of the tee is connected to the inlet of the gas phase pressure sensor 45 by a ferrule, and the outlet of the gas phase pressure sensor 45 is connected to the inlet of the first gas phase solenoid valve 46 by a ferrule; the outlet of the first gas phase solenoid valve 46 is connected to a tee inlet by a ferrule, and the first outlet of the tee is connected to the inlet of the first gas phase pipeline manual needle valve 47 by a ferrule; the outlet of the first gas phase pipeline manual needle valve 47 is connected to the gas chromatograph sampler; the second outlet of the tee is connected to the inlet of the second gas phase pipeline manual needle valve 48 by a ferrule, and the outlet of the second gas phase pipeline manual needle valve 48 is connected to the hydrogen sulfide analyzer by a ferrule.

[0128] Component analysis

[0129] The liquid phase analysis module is used to analyze specific components in the liquid phase, which is divided into ion chromatography analysis and liquid chromatography analysis.

[0130] Liquid phase analysis is divided into two routes. One route is composed of the fourth pressure sensor 35, the first liquid phase solenoid valve 37, the second liquid phase pipeline manual needle valve 39, the liquid chromatograph 64 and the fourth liquid phase pipeline manual needle valve; the other route is composed of the fifth pressure sensor 36, the second liquid phase solenoid valve 38, the ion chromatograph 63, and the ion chromatograph drainage pipeline manual needle valve 42. The above solenoid valves are used for emergency cutoff, and the manual needle valves are used for normal test analysis and adjustment.

[0131] The gas phase analysis module is used to analyze the gas phase components of the output, which consists of a gas chromatograph and a hydrogen sulfide analyzer. Since hydrogen sulfide exists as an interfering gas component in the chromatographic column, it is analyzed separately.

[0132] The gas phase analysis module is also implemented in two ways, including a pressure sensor 45 and a first gas phase solenoid valve 46; the first gas phase solenoid valve 46 is divided into two ways, one way is connected to the gas chromatograph 62 and the manual needle valve 49 of the gas chromatograph exhaust line through the first gas phase pipeline manual needle valve 47, and the other way is connected to the hydrogen sulfide analyzer 65 and the fourth gas phase pipeline manual needle valve 50 of the hydrogen sulfide analyzer exhaust line through the second gas phase pipeline manual needle valve 48. The electromagnetic ball valve is used for quick cut-off, and the manual needle valve is used for test analysis and adjustment.

[0133] Although the embodiments of the present invention are described above in conjunction with the accompanying drawings, the present invention is not limited to the above-mentioned specific embodiments and application fields, and the above-mentioned specific embodiments are only illustrative and instructive, rather than restrictive. Under the guidance of the specification, a person skilled in the art can also make many forms without departing from the scope of protection of the claims of the present invention, all of which belong to the scope of protection of the present invention.

Claims

1. A system for sampling and detecting annular fluid in a high-temperature and high-pressure gas well, characterized in that: It includes a sampling and decompression module, a gas-liquid separation module, a component analysis module and a data acquisition module; The sampling and decompression module is used to decompress and sample the annular fluid, transmit the sampled annular fluid to the gas-liquid separation module, perform data measurement, and transmit the measured data to the data acquisition module; The gas-liquid separation module is used to perform gas-liquid separation on the sampled annular fluid to obtain the separated annular fluid, transmit the separated annular fluid to the component analysis module, perform data measurement on the annular fluid after gas-liquid separation, and transmit the measured data to the data acquisition module; The component analysis module is used to perform gas-liquid phase analysis on the gas phase and liquid phase fluids in the gas-liquid separation module, and send the analysis results to the data acquisition module; The data acquisition module is used to receive the annular space fluid data before decompression, the annular space fluid data measured by the sampling decompression module, the annular space fluid data measured by the gas-liquid separation module and the component analysis module data.

2. The annulus fluid sampling and detection system for high-temperature and high-pressure gas wells according to claim 1, characterized in that: The sampling decompression module comprises a collection unit, a primary decompression unit and a secondary decompression unit which are connected in sequence.

3. The annulus fluid sampling and detection system for high-temperature and high-pressure gas wells according to claim 2, characterized in that: The first-level pressure reducing unit is two pipelines connected in parallel, one of which is a pressure reducing pipeline and the other is a normal pipeline, and the two pipelines are not opened at the same time.

4. The annulus fluid sampling and detection system for high-temperature and high-pressure gas wells according to claim 1, characterized in that: The gas-liquid separation module includes a gas-liquid separation unit, a liquid phase unit and a gas phase unit. The gas-liquid separation unit is used to perform gas-liquid separation of annular space fluid. The liquid phase unit and the gas phase unit are respectively connected to both sides of the gas-liquid separation unit to collect liquid phase data and gas phase data of the annular space fluid respectively.

5. The annulus fluid sampling and detection system for high-temperature and high-pressure gas wells according to claim 1, characterized in that: The data acquisition module comprises a data collector, a signal converter, a data analyzer, a signal remote transmitter and a display which are connected in sequence.

6. The annulus fluid sampling and detection system for high-temperature and high-pressure gas wells according to claim 1, characterized in that: The component analysis module includes a gas phase analysis unit and a liquid phase analysis unit.

7. The annulus fluid sampling and detection system for high-temperature and high-pressure gas wells according to claim 6, characterized in that: The gas phase analysis unit includes a gas chromatograph and a hydrogen sulfide analyzer.

8. The annulus fluid sampling and detection system for high-temperature and high-pressure gas wells according to claim 6, characterized in that: The liquid phase analysis unit includes an ion chromatograph and a liquid chromatograph.

9. The annulus fluid sampling and detection system for high-temperature and high-pressure gas wells according to claim 1, characterized in that: The sampling decompression module is arranged inside the explosion-proof box and is used to be connected to the wellhead annulus.

10. A method for sampling and detecting annular fluid in a high-temperature and high-pressure gas well, characterized in that: include: Acquire the annular fluid, decompress the annular fluid to obtain the decompressed annular fluid, and collect data on the decompressed annular fluid to obtain the decompressed annular fluid data; Performing gas-liquid separation on the annular fluid after decompression to obtain separated annular fluid, and performing data measurement on the sampled material after gas-liquid separation to obtain separated annular fluid data; Perform component analysis on the gas phase and liquid phase after gas-liquid separation to obtain component analysis data; Collect annular fluid data before and after decompression, annular fluid data after gas-liquid separation, and component analysis data.

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