Experimental device for correcting gas logging late time

Abstract

The present application relates to the experimental device of correction gas logging late time, including drilling fluid tank, wellbore, hydrocarbon gas storage tank, fluorescent fluid tank, data processor;The wellbore is fixed after the height difference is formed in two ends, the drilling fluid tank is connected with the lower end of wellbore through pipeline, the hydrocarbon gas storage tank, fluorescent fluid tank are connected with the pipeline through gas injection pipe, liquid injection pipe respectively, and the pipeline, gas injection pipe, liquid injection pipe are all installed with conveying pump, the higher end of wellbore forms outlet, and infrared laser concentration monitor and fluorescence analyzer are installed at the outlet, and the infrared laser concentration monitor and fluorescence analyzer are all connected with the data processor circuit.The experimental device of correction gas logging late time of the present application obtains the time of dissolved gas and free gas in hydrocarbon gas reaching wellhead through visual tracking technology and infrared laser identification technology, and corrects the inaccurate problem of late time in gas logging.

Description

Technical Field

[0001] This invention belongs to the field of oil and gas engineering technology, and in particular relates to an experimental device for correcting the late arrival time of gas logging. Background Technology

[0002] Gas logging is a key technology in oil and gas development. This technology obtains reservoir oil and gas information at different depths by measuring the hydrocarbon gas content in the drilling fluid returning to the wellhead. After the drill bit breaks through the rock, hydrocarbon gases escape from the rock. Some of these hydrocarbon gases dissolve in the drilling fluid, called dissolved gas; the rest remain insoluble, called free gas. The time it takes for hydrocarbon gases to return from the bottom of the well to the wellhead is called the lag time. Free gas, due to buoyancy and its lighter weight, travels faster in the wellbore and arrives at the wellhead before dissolved gas. Dissolved gas, influenced by drilling fluid density, viscosity, temperature, and flow rate, arrives at the wellhead later than free gas. Inaccurate prediction of the lag time makes it difficult to determine the depth of hydrocarbon gas detection, leading to inaccurate reservoir hydrocarbon gas content detection.

[0003] Through literature review, some gas logging experimental devices have been developed to improve the degassing efficiency of degassing devices or to study the impact of different influencing factors on gas logging data. Examples include a downhole gas logging test device (CN201720060698.5) and a Fourier transform infrared gas logging method and device (CN201910717334.3). However, none of these devices can correct for the late arrival time of gas logging.

[0004] Therefore, based on these issues, providing an experimental device that uses visual tracking technology and infrared laser recognition technology to obtain the arrival time of dissolved gas and free gas in hydrocarbon gases at the wellhead, and corrects the inaccuracy of late arrival time in gas logging, has important practical significance. Summary of the Invention

[0005] The purpose of this invention is to overcome the shortcomings of the prior art and provide an experimental device that uses visual tracking technology and infrared laser recognition technology to obtain the arrival time of dissolved gas and free gas in hydrocarbon gases at the wellhead, and to correct the inaccuracy of late arrival time in gas logging.

[0006] The technical problem solved by this invention is achieved through the following technical solution:

[0007] An experimental setup for correcting late arrival times in gas logging includes a drilling fluid tank, wellbore, hydrocarbon gas storage tank, fluorescent fluid tank, and data processor.

[0008] After the wellbore is fixed, a height difference is formed at both ends. The drilling fluid tank is connected to the lower end of the wellbore through a pipeline. The hydrocarbon gas storage tank and the fluorescent fluid tank are connected to the pipeline through gas injection pipe and liquid injection pipe, respectively. A delivery pump is installed on the pipeline, gas injection pipe, and liquid injection pipe. An outlet is formed at the higher end of the wellbore. An infrared laser concentration monitor is installed at the outlet. Fluorescent analyzers are distributed along the axial direction of the wellbore. Both the infrared laser concentration monitor and the fluorescent analyzers are connected to the data processor circuit.

[0009] Furthermore, a booster pump is installed at the lower end of the wellbore, and a pressure relief valve is installed at the higher end of the wellbore.

[0010] Furthermore, the pressure relief valve is installed upstream of the infrared laser concentration monitor and the fluorescence analyzer.

[0011] Furthermore, the fluorescence analyzer includes an exciter and a receiver. The exciter irradiates the fluorescent fluid with X-rays to make it reflect fluorescence, and the receiver receives the fluorescence of the fluorescent fluid and records the time when the fluorescent fluid arrives at the wellhead.

[0012] Furthermore, the fluorescence analyzer is installed inside the side wall of the wellbore.

[0013] Furthermore, a degassing tank is connected to the outlet of the wellbore, and a degassing device is installed on the top of the degassing tank.

[0014] Furthermore, the gas expelled from the degasser is connected to a gas analyzer via a gas pipeline. The gas analyzer detects the expelled gas and is connected to the data processor circuit.

[0015] Furthermore, a drain pipe is installed at the bottom of the degassing tank, and the outlet end of the drain pipe is connected to a waste liquid tank.

[0016] Furthermore, the fluorescent fluid in the fluorescent fluid chamber includes glyoxylic acid and catechol.

[0017] Furthermore, an air pump, a first liquid pump, and a second liquid pump are respectively installed on the air injection pipe, the liquid injection pipe, and the pipeline, and the second liquid pump is located upstream of the air pump and the first liquid pump.

[0018] The advantages and positive effects of this invention are:

[0019] The experimental device for correcting the late arrival time of gas logging in this invention obtains the arrival time of dissolved gas and free gas in hydrocarbon gases at the wellhead through visual tracking technology and infrared laser recognition technology, thereby correcting the problem of inaccurate late arrival time in gas logging. Attached Figure Description

[0020] The technical solution of the present invention will be further described in detail below with reference to the accompanying drawings and embodiments. However, it should be understood that these drawings are designed for illustrative purposes only and are not intended to limit the scope of the present invention. Furthermore, unless specifically indicated, these drawings are intended only to conceptually illustrate the structural construction described herein and are not necessarily drawn to scale.

[0021] Figure 1 This is a schematic diagram of the experimental device for correcting the late arrival time of gas logging provided in an embodiment of the present invention;

[0022] Figure 2 This is a schematic diagram of the structure of the fluorescent analyzer installed inside the wellbore sidewall of the experimental device for correcting the late arrival time of gas logging provided in an embodiment of the present invention.

[0023] Figure 3 A cross-sectional view of the structure of the fluorescence analyzer installed inside the wellbore sidewall of the experimental device for correcting the late arrival time of gas logging provided in an embodiment of the present invention. Detailed Implementation

[0024] First, it should be noted that the specific structure, features, and advantages of the present invention will be described in detail below by way of examples. However, all descriptions are for illustrative purposes only and should not be construed as limiting the present invention in any way. Furthermore, any single technical feature described or implied in the various embodiments mentioned herein can still be arbitrarily combined or deleted among these technical features (or their equivalents) to obtain more other embodiments of the present invention that may not be directly mentioned herein.

[0025] It should be noted that the terminology used herein is for the purpose of describing particular implementations only and is not intended to limit the exemplary implementations according to this application. As used herein, unless the context clearly indicates otherwise, the singular form is also intended to include the plural form. Furthermore, the terms “comprising” and “having”, and any variations thereof, are intended to cover a non-exclusive inclusion, for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0026] It should be noted that, unless otherwise specified, the embodiments and features described in this application can be combined with each other.

[0027] Example

[0028] See Figure 1 , 23. This embodiment provides an experimental device for correcting the late arrival time of gas logging, including a drilling fluid tank 1, a wellbore 11, a hydrocarbon gas storage tank 3, a fluorescent fluid box 7, and a data processor 10;

[0029] After the wellbore 11 is fixed, a height difference is formed at both ends. The drilling fluid tank 1 is connected to the lower end of the wellbore 11 through a pipe 17. The hydrocarbon gas storage tank 3 and the fluorescent fluid tank 7 are connected to the pipe 17 through an injection pipe 5 and an injection pipe 6, respectively. A delivery pump is installed on the pipe 17, the injection pipe 5, and the injection pipe 6. An outlet is formed at the higher end of the wellbore 11. An infrared laser concentration monitor 15 is installed at the outlet. Fluorescent analyzers 112 are distributed along the axial direction of the wellbore. Both the infrared laser concentration monitor 15 and the fluorescent analyzers 112 are connected to the data processor 10 circuit.

[0030] A booster pump 8 is installed at the lower end of the wellbore 11 to control the flow process and flow pressure of the drilling fluid; a pressure relief valve 14 is installed at the higher end of the wellbore 11 to ensure that the drilling fluid flows out from the outlet at a low speed and stably; and the pressure relief valve 14 is installed upstream of the infrared laser concentration monitor 15 and the fluorescence analyzer 112.

[0031] The fluorescence analyzer 112 includes an exciter 114 and a receiver 115. The exciter irradiates the fluorescent fluid with X-rays to make it reflect fluorescence, and the receiver receives the fluorescence of the fluorescent fluid to determine the migration trajectory of the fluorescent fluid in the wellbore 11 and record the time when the fluorescent fluid arrives at the wellhead, thus forming a visual tracking technology for the arrival of dissolved gas at the wellhead.

[0032] The fluorescence analyzer 112 is installed inside the side wall of the wellbore 11. In this embodiment, the fluorescence analyzer 112 is a ring-shaped structure, located between the inner wall 111 and the outer wall 113 of the wellbore, and is fixed by the inner wall 111 and the outer wall 113 of the wellbore. It is mainly used to track the migration state of dissolved gas in the wellbore 11. The fluorescent fluid in the fluorescent fluid box 7 includes glyoxylic acid and catechol, which can exist in the drilling fluid in molecular form and the fluorescent fluid molecules can enter the effective pores of water molecules, simulating the dissolved gas in the drilling fluid. The state of existence; the fluorescence analyzer 112 is connected to the data processor 10 to scan the drilling fluid and fluorescent fluid in the wellbore in real time, determine the migration trajectory of the fluorescent fluid in the wellbore 11, record the time when the fluorescent fluid arrives at the wellhead, and form a visual tracking technology for the arrival of dissolved gas at the wellhead; the wellbore 11 is supported by the wellbore support 12 fixed on the support base 13, and the wellbore 11 is 30m long; the bottom of the well is connected to the booster pump 8 to control the flow process and flow pressure of the drilling fluid, and the wellhead is connected to the pressure relief valve 14 to ensure that the drilling fluid flows out of the wellhead at a low speed and stably.

[0033] The outlet of the wellbore 11 is connected to a degassing tank 19, and a degasser 18 is installed on the top of the degassing tank 19. The degasser 18 is connected to a gas analyzer 21 through a gas outlet pipe 22 to analyze the gas degassing from the degasser 18 and is connected to a data processor circuit. A drain pipe 20 is installed at the bottom of the degassing tank 19, and the outlet end of the drain pipe 20 is connected to a waste liquid tank 16.

[0034] An air pump 4, a first liquid pump 601, and a second liquid pump 2 are respectively installed on the air injection pipe 5, the liquid injection pipe 6, and the pipe 17, with the second liquid pump located upstream of the air pump and the first liquid pump.

[0035] Drilling fluid is injected into the wellbore 11 from the drilling fluid tank 1 through the pipeline 17, and fluorescent fluid is injected into the pipeline 17 from the fluorescent fluid tank 7 through the injection pipe 6. In this embodiment, hydrocarbon gas is stored in the hydrocarbon gas storage tank 3, which simulates free gas. The free gas is injected into the pipeline 17 through the gas injection pipe 5. The gas injection pipe 5 is connected in series with the hydrocarbon gas storage tank 3 and the gas pump 4. The gas injection pipe 5 is connected to the injection pipe 6 through the connection port.

[0036] The infrared laser concentration monitor can be the MS600 six-in-one gas concentration detector. By monitoring the sudden change in free gas concentration at the wellhead from zero to one, it determines the time when free gas arrives at the wellhead, thus forming an infrared laser recognition technology for free gas arrival at the wellhead. The infrared laser concentration monitor 15 is connected to the data processor 10, and the data processor 10 records the free gas concentration in real time.

[0037] Gas meter 21 monitors the sudden change process of hydrocarbon gas from zero to presence at the degasser 18 at the wellhead, and determines the time when the hydrocarbon gas arrives at the wellhead; gas meter 21 is connected to data processor 10, and data processor 10 records the concentration of gas released from the degasser detected by gas meter 21 in real time.

[0038] according to Figure 1 The injection pipe 6 is connected in series with the fluorescent fluid tank 7 and is connected to the pipeline 17 through the connection port. The first liquid pump 601 pumps the fluorescent fluid into the pipeline 17 to mix with the drilling fluid. The gas injection pipe 5 is connected in series with the gas pump 4 and the hydrocarbon gas storage tank 3 and is connected to the injection pipe 6 through the connection port. The gas injection pipe 5 extends into the connection between the injection pipe 6 and the pipeline 17. The gas pump 4 pumps the hydrocarbon gas in the hydrocarbon gas storage tank 3 into the pipeline 17 through the gas injection pipe 5 to mix with the drilling fluid. At the beginning of the experiment, the gas pump 4 and the first liquid pump 601 are turned on at the same time to inject the free gas and the fluorescent fluid into the drilling fluid in the pipeline 17.

[0039] according to Figure 1 Pipeline 17 connects drilling fluid tank 1, second liquid pump, and wellbore 11 in series; second liquid pump 2 is responsible for pumping drilling fluid from drilling fluid tank 1 into wellbore 11 through pipeline 17; drain pipe 20 is responsible for draining drilling fluid into waste liquid tank 16.

[0040] As an example, in this embodiment, the method for correcting the late time of gas logging using the experimental apparatus for correcting the late time of gas logging according to the present invention is as follows:

[0041] Step 1: Start the experimental setup: Turn on the power, and start the fluorescence analyzer, infrared laser concentration monitor, and data processor;

[0042] Step 2: Pumping in drilling fluid: Turn on the second liquid pump 2 to pump the drilling fluid into the pipeline 17, so that the drilling fluid passes through the pipeline 17, the wellbore 11, the drain pipe 20 and the waste liquid tank 16 in sequence. When the drilling fluid is circulating and the flow pressure is stable, start the next step.

[0043] Step 3: Inject free gas and fluorescent fluid and record the injection time. Turn on the gas pump 4 to pump the hydrocarbon gas into the pipeline 17 through the gas injection pipe 5. At the same time, turn on the first liquid pump 601 to pump the fluorescent fluid into the pipeline 17 through the liquid injection pipe 6. Record the injection time of free gas and fluorescent fluid as T0.

[0044] Step 4: Record the time when free gas arrives at the wellhead: Identify the change in free gas concentration at the wellhead using the infrared laser concentration monitor 15, and record the moment when the free gas concentration is not 0 for the first time. This moment is the time when free gas arrives at the wellhead, denoted as T1.

[0045] Step 5: Record the time when dissolved gas arrives at the wellhead: The fluorescent fluid in the wellbore 11 is tracked in real time by the fluorescence analyzer 112. When the fluorescent fluid arrives at the wellhead, it is the time when dissolved gas arrives at the wellhead, which is recorded as time T2.

[0046] Step 6: Record the time when the hydrocarbon gas released from the degasser 18 at the wellhead, monitored by the gas meter 21, reaches the wellhead; and record the moment when the hydrocarbon gas concentration is not 0 for the first time. This moment is the time when the hydrocarbon gas released from the degasser 18 reaches the wellhead, denoted as T3.

[0047] Step 7: Calculate the late time:

[0048] ΔT1=T1-T0

[0049] ΔT2=T2-T0

[0050] ΔT3=T3-T0

[0051] In the formula: ΔT is the delay time; T0 is the injection time of free gas and fluorescent fluid; T1 is the time when free gas arrives at the wellhead; T2 is the time when fluorescent fluid arrives at the wellhead; T3 is the time difference between the arrival of hydrocarbon gas detected by the gas meter at the wellhead.

[0052] Step 8: Change factors such as drilling fluid density, viscosity, and pressure, and repeat steps 1-7 to calculate the delay time under different factors;

[0053] Step 9: Data Processing: Fit experimental data on density and late time, viscosity and late time, and pressure and late time to obtain functions relating density, viscosity, pressure, and late time.

[0054] The above embodiments have provided a detailed description of the present invention, but the content described is only a preferred embodiment of the present invention and should not be considered as limiting the scope of the present invention. All equivalent variations and improvements made within the scope of the present invention should still fall within the patent coverage of the present invention.

Claims

1. An experimental method for correcting the late arrival time of gas logging, characterized in that: The experimental setup for correcting the late arrival time of gas logging includes a drilling fluid tank, wellbore, hydrocarbon gas storage tank, fluorescent fluid box, and data processor; After the wellbore is fixed, a height difference is formed at both ends. The drilling fluid tank is connected to the lower end of the wellbore via a pipeline. The hydrocarbon gas storage tank and the fluorescent fluid tank are connected to the pipeline via gas injection pipe and liquid injection pipe, respectively. A delivery pump is installed on each of the pipeline, gas injection pipe, and liquid injection pipe. An outlet is formed at the higher end of the wellbore, and an infrared laser concentration monitor is installed at the outlet. Fluorescent analyzers are distributed along the axial direction of the wellbore. Both the infrared laser concentration monitor and the fluorescent analyzers are connected to the data processor circuit. A degassing tank is connected to the outlet of the wellbore, and a degasser is installed at the top of the degassing tank. The gas degassed by the degasser is connected to a gas detector via a gas pipeline. The gas detector detects the degassed gas and is connected to the data processor circuit. A gas pump, a first liquid pump, and a second liquid pump are installed on the gas injection pipe, liquid injection pipe, and pipeline, respectively, with the second liquid pump located upstream of the gas pump and the first liquid pump. The method includes the following steps: Step 1: Start the experimental setup: Turn on the power, and start the fluorescence analyzer, infrared laser concentration monitor, and data processor; Step 2: Pumping in drilling fluid: Turn on the second liquid pump to pump the drilling fluid into the pipeline, so that the drilling fluid passes through the pipeline, wellbore, drain pipe and waste tank in sequence. When the drilling fluid is circulating and the flow pressure is stable, proceed to the next step. Step 3: Inject free gas and fluorescent fluid and record the injection time. Turn on the gas pump to pump the hydrocarbon gas into the pipeline through the gas injection tube, and at the same time turn on the first liquid pump to pump the fluorescent fluid into the pipeline through the liquid injection tube. Record the injection time of free gas and fluorescent fluid as T0. Step 4: Record the time when free gas arrives at the wellhead: Identify the change in free gas concentration at the wellhead using an infrared laser concentration monitor, and record the moment when the free gas concentration is not zero for the first time. This moment is the time when free gas arrives at the wellhead, denoted as T1. Step 5: Record the time when dissolved gas arrives at the wellhead: The movement trajectory of the fluorescent fluid in the wellbore is tracked in real time by the fluorescence analyzer. When the fluorescent fluid arrives at the wellhead, it is the time when the dissolved gas arrives at the wellhead, which is recorded as time T2. Step 6: Record the time when the hydrocarbon gas released from the degasser at the wellhead reaches the wellhead, as monitored by the gas meter: and record the moment when the hydrocarbon gas concentration is not 0 for the first time. This moment is the time when the hydrocarbon gas released from the degasser reaches the wellhead, denoted as T3. Step 7: Calculate the late time: ； ； ； In the formula: Δ T i For the late arrival time, i = 1, 2, 3; T0 is the injection time of free gas and fluorescent fluid; T1 is the time when free gas arrives at the wellhead; T2 is the time when fluorescent fluid arrives at the wellhead; T3 is the time difference between the arrival time of hydrocarbon gas detected by the gas meter at the wellhead; Step 8: Change the drilling fluid density, viscosity, and pressure factors, and repeat steps 1-7 to calculate the delay time under different factors; Step 9: Data Processing: Fit experimental data on density and late time, viscosity and late time, and pressure and late time to obtain functions relating density, viscosity, pressure factor, and late time.

2. The experimental method for correcting the late arrival time of gas logging according to claim 1, characterized in that: A booster pump is installed at the lower end of the wellbore, and a pressure relief valve is installed at the higher end of the wellbore.

3. The experimental method for correcting the late arrival time of gas logging according to claim 2, characterized in that: The pressure relief valve is installed upstream of the infrared laser concentration monitor and the fluorescence analyzer.

4. The experimental method for correcting the late arrival time of gas logging according to claim 1, characterized in that: The fluorescence analyzer includes an exciter and a receiver. The exciter irradiates the fluorescent fluid with X-rays to make it reflect fluorescence, and the receiver receives the fluorescence of the fluorescent fluid and records the time when the fluorescent fluid reaches the wellhead.

5. The experimental method for correcting the late arrival time of gas logging according to claim 4, characterized in that: The fluorescence analyzer is installed inside the side wall of the wellbore.

6. The experimental method for correcting the late arrival time of gas logging according to claim 1, characterized in that: A drain pipe is installed at the bottom of the degassing tank, and the outlet end of the drain pipe is connected to a waste liquid tank.

7. The experimental method for correcting the late arrival time of gas logging according to claim 1, characterized in that: The fluorescent fluid in the fluorescent fluid chamber includes glyoxylic acid and catechol.

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