CN114109357A - Deepwater gas cut simulation experiment device and gas cut judgment method - Google Patents
Deepwater gas cut simulation experiment device and gas cut judgment method Download PDFInfo
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- CN114109357A CN114109357A CN202111549646.1A CN202111549646A CN114109357A CN 114109357 A CN114109357 A CN 114109357A CN 202111549646 A CN202111549646 A CN 202111549646A CN 114109357 A CN114109357 A CN 114109357A
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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 DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/001—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor specially adapted for underwater drilling
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
Abstract
The invention discloses a deepwater gas cut simulation experiment device and a gas cut judgment method, wherein the device comprises: a containment tank, filled into the manifold; the injection manifold is internally provided with an injection flow detection piece; a circulation pump; the upper end of the simulation drill rod is communicated with the injection manifold; the simulation marine riser is sleeved outside the simulation drill rod, and a first annular gap is formed between the simulation drill rod and the simulation marine riser; the simulation well bore is sleeved outside the simulation drill rod, the upper end of the simulation well bore is connected with the lower end of the simulation marine riser in a sealing mode, a second annular gap is formed between the simulation well bore and the simulation drill rod, and the length of at least one of the simulation marine riser and the simulation well bore can be changed along the axial direction; the flow detection assembly is used for detecting the flow in the first annular gap and the second annular gap; and one end of the gas manifold is communicated with the lower end of the simulation drill rod, the other end of the gas manifold is connected with a gas source, and the gas manifold is provided with a switch valve and a gas flow detection piece. The invention can carry out deep water gas cut simulation experiments of different water depths and can guide the gas cut identification.
Description
Technical Field
The invention relates to the technical field of ocean deepwater drilling, in particular to a deepwater gas invasion simulation experiment device and a gas invasion judgment method.
Background
In order to increase the area of exploration and development areas of marine oil and gas, more oil and gas discoveries are sought, and the exploration and development operations of marine oil and gas are gradually shifted from shallow sea offshore areas to deep sea offshore areas. Ocean deep water drilling generally refers to drilling at sea operating water depths of over 900 meters. At present, a great problem faced by the ocean deepwater drilling and completion operation is the well control problem brought by deepwater. The deepwater operation is slower than the gas cutting condition discovery of land and shallow water operation, and the well control difficulty is higher.
Gas cutting is a particularly problematic problem during deep sea drilling. Timely gas cut monitoring can provide a large amount of safe time allowance for deep water field well control operation, and large economic and personnel losses are avoided even for field recovery. However, the current field gas invasion monitoring often cannot provide guarantee for well control operation, and the gas invasion monitoring is seriously lagged.
Due to the characteristics of compression and expansion of the gas, the gas is influenced by the pressure of an upper liquid column when entering the drilling fluid at the bottom of the well, so that the gas volume is small; along with the circulation and upward return of the drilling fluid, the gas rising speed is higher and higher, the liquid column pressure borne by the gas is gradually reduced, and the gas volume is gradually expanded and increased; especially as the gas approaches the surface, the expansion of the gas increases rapidly. Thus, even if the drilling fluid returning to the surface is very aggressive, forms many bubbles, and has a much lower density, the absolute value of the reduction in drilling fluid column pressure is still small. For example, even if the surface gas-invaded drilling fluid density is only half of the original drilling fluid density, the drilling fluid column pressure reduction does not exceed 0.4 Mpa.
In the drilling process, if gas invasion cannot be effectively monitored and effective degassing measures are taken, gas invasion drilling fluid is repeatedly pumped into a well, so that the gas invasion degree of the drilling fluid is more serious, the bottom hole pressure is continuously reduced, and the risk of overflow or blowout occurs.
In summary, in order to ensure the safe development of the deepwater oil and gas field, a deepwater oil and gas field gas invasion simulation experiment with different water depths needs to be developed urgently, the flow mode in a shaft during deepwater oil and gas field gas invasion is determined, and reference is provided for deepwater well drilling safety control.
Disclosure of Invention
The invention aims to provide a deepwater gas cut simulation experiment device and a gas cut judgment method, which can perform deepwater gas cut simulation experiments of different water depths, accurately identify gas cut, determine a flow mode in a shaft during gas cut of a deepwater oil-gas field and provide reference for deepwater well drilling safety control.
The specific technical scheme in the embodiment of the invention is as follows:
a deepwater gas cut simulation experiment device comprises: the accommodating pool is used for accommodating drilling fluid; an injection manifold, one end of which extends into the holding tank; a liquid injection flow detection piece is arranged in the injection manifold; the circulating pump is arranged in the injection manifold and used for pumping out the drilling fluid in the accommodating pool to provide power; the upper end of the simulation drill rod is communicated with the injection manifold; the simulation marine riser is sleeved outside the simulation drill rod, and a first annular gap is formed between the simulation drill rod and the simulation marine riser; the simulation well bore is sleeved outside the simulation drill pipe, the upper end of the simulation well bore is connected with the lower end of the simulation marine riser in a sealing mode, a second annular gap is formed between the simulation well bore and the simulation drill pipe, and the length of at least one of the simulation marine riser and the simulation well bore can be changed along the axial direction; a flow sensing assembly comprising at least: the flow meters are arranged close to the lower end of the simulation marine riser and close to the lower end of the simulation well shaft; and one end of the gas manifold is communicated with the lower end of the simulation drill rod, the other end of the gas manifold is connected with a gas source, and the gas manifold is provided with a switch valve and a gas flow detection piece.
In a preferred embodiment, the simulation riser includes a first simulation sub-riser and a second simulation sub-riser that are sleeved together, a first sealing member is disposed at an overlapping position of the first simulation sub-riser and the second simulation sub-riser along an axial direction, a first fixing member is disposed on the first sealing member, and the first simulation sub-riser and the second simulation sub-riser can move relatively along the axial direction.
In a preferred embodiment, the simulated well bore comprises a first simulated sub well bore and a second simulated sub well bore which are sleeved with each other, a second sealing element is arranged at the overlapping position of the first simulated sub well bore and the second simulated sub well bore along the axial direction, a second fixing element is arranged on the second sealing element, and the first simulated sub well bore and the second simulated sub well bore can move relatively along the axial direction.
In a preferred embodiment, the wall of the simulated riser is corrugated to form a telescoping tube.
In a preferred embodiment, the simulation riser and the simulation wellbore are made of transparent materials, and the deepwater gas cut simulation experiment apparatus further includes: the image acquisition equipment, with image acquisition equipment electric connection's controller.
In a preferred embodiment, the deepwater gas cut simulation experiment device further comprises a return manifold, an outlet is arranged at a position, close to the upper end, of the simulation marine riser, one end of the return manifold is connected to the outlet, and the other end of the return manifold is connected to the accommodating pool.
In a preferred embodiment, a gas-liquid separation device is further provided in the return manifold.
In a preferred embodiment, the flow rate detection assembly includes a first ultrasonic detector for monitoring the lower end of the simulation riser, a second ultrasonic detector for monitoring the upper end of the simulation riser, a third ultrasonic detector for monitoring the flow rate of the injection manifold, a fourth ultrasonic detector for monitoring the upper end of the simulation shaft, and a fifth ultrasonic detector for monitoring the lower end of the simulation shaft, and the gas flow rate detector is a sixth ultrasonic detector disposed in the gas manifold.
A gas cut judging method of a deepwater gas cut simulation experiment device comprises the following steps:
well depth and the length of a marine riser are adjusted, and a drilling fluid circulating pump is started, so that the whole pipeline and a deep water gas cut simulation experiment are filled with drilling fluid;
after the circulation is stable, recording the data of the third ultrasonic flowmeter, opening the switch valve, monitoring the sixth ultrasonic flowmeter, releasing a L gas, and then closing the switch valve;
monitoring data of a first ultrasonic flow meter, a second ultrasonic flow meter, a fourth ultrasonic flow meter and a fifth ultrasonic flow meter;
and judging whether the total overflow volume is greater than or equal to a preset value or not based on the flow of the ultrasonic flowmeter, judging whether the total overflow volume is greater than or equal to the preset value or not within a preset time when the conditions are met, and judging that gas invasion has occurred at present and the well needs to be shut down if the judgment result is yes.
In a preferred embodiment, the total overflow QYDetermined by the following equation:
QY＝Av(1-Eg)△t-q0△t
wherein A is the cross-sectional area of the annular space, m2(ii) a v is the flow rate measured in the pipe flow, measured by a third ultrasonic flow meter, m/s; egSection air void,%; Δ t is the time increment, s; q. q.s0Is the flow rate of the pump; qYThe increment of the overflow in the delta t time; rhogIs gas density, g/cm3；ρlIs liquid density, g/cm3；vlMeasuring the flow rate of the fluid by a first ultrasonic flowmeter, a second ultrasonic flowmeter, a fourth ultrasonic flowmeter and a fifth ultrasonic flowmeter, wherein m/s is the flow rate of the fluid; v. ofgMeasured by a sixth ultrasonic flow meter, m/s, is the gas flow rate.
In a preferred embodiment, the method further comprises: when the total overflow amount is smaller than the preset value, a L is used as the increasing released gas amount, and the judgment process is repeated.
A gas cut judging method of a deepwater gas cut simulation experiment device comprises the following steps:
well depth and the length of a marine riser are adjusted, and a drilling fluid circulating pump is started, so that the whole pipeline and a deep water gas cut simulation experiment are filled with drilling fluid;
after the circulation is stable, recording the data of the third ultrasonic flowmeter, opening a switch valve, monitoring the sixth ultrasonic flowmeter, and filling gas at a preset speed;
monitoring data of a first ultrasonic flow meter, a second ultrasonic flow meter, a fourth ultrasonic flow meter and a fifth ultrasonic flow meter;
and judging whether the total overflow volume is greater than or equal to a preset value or not based on the flow of the ultrasonic flowmeter, judging whether the total overflow volume is greater than or equal to the preset value or not within a preset time when the conditions are met, and judging that gas invasion has occurred at present and the well needs to be shut down if the judgment result is yes.
In a preferred embodimentIn one embodiment, the total overflow QYDetermined by the following equation:
QY＝Av(1-Eg)△t-q0△t
wherein A is the cross-sectional area of the annular space, m2(ii) a v is the flow rate measured in the pipe flow, measured by a third ultrasonic flow meter, m/s; egSection air void,%; Δ t is the time increment, s; q. q.s0Is the flow rate of the pump; qYThe increment of the overflow in the delta t time; rhogIs gas density, g/cm3；ρlIs liquid density, g/cm3；vlMeasuring the flow rate of the fluid by a first ultrasonic flowmeter, a second ultrasonic flowmeter, a fourth ultrasonic flowmeter and a fifth ultrasonic flowmeter, wherein m/s is the flow rate of the fluid; v. ofgMeasured by a sixth ultrasonic flow meter, m/s, is the gas flow rate.
The technical scheme of this application has and shows beneficial effect:
the application provides a deepwater gas invasion simulation experiment device and a gas invasion judgment method aiming at deepwater oil and gas fields, wherein the deepwater gas invasion simulation experiment device can truly simulate deepwater gas invasion environments, can simulate deepwater gas invasion simulation experiments at different water depths, can accurately identify gas invasion, determine a flow pattern in a shaft during deepwater oil and gas field gas invasion, and provide reference for deepwater well drilling safety control. The judgment of the gas invasion is not only qualitative judgment, but also provides an accurate quantitative judgment mode, and provides a reliable prejudgment basis for actual production.
Specific embodiments of the present invention are disclosed in detail with reference to the following description and drawings, indicating the manner in which the principles of the invention may be employed. It should be understood that the embodiments of the invention are not so limited in scope. The embodiments of the invention include many variations, modifications and equivalents within the spirit and scope of the appended claims. Features that are described and/or illustrated with respect to one embodiment may be used in the same way or in a similar way in one or more other embodiments, in combination with or instead of the features of the other embodiments.
Drawings
FIG. 1 is a schematic structural diagram of a deepwater gas cut simulation experiment device according to an embodiment of the present disclosure;
FIG. 2 is a schematic structural diagram of a simulated riser and simulated wellbore engagement location provided in an embodiment of the present application;
FIG. 3 is a flowchart illustrating steps of a deep water gas migration simulation experiment method according to an embodiment of the present disclosure;
FIG. 4 is a plot of cross-sectional gas void fraction versus time at various ultrasonic flow meters;
FIG. 5 is a graph of total overflow volume versus time;
FIG. 6 is a schematic illustration of a flow pattern as a bubble flow;
FIG. 7 is a schematic view of a flow pattern in the form of a bullet flow;
FIG. 8 is a schematic illustration of a flow regime as slugging;
FIG. 9 is a schematic view of a flow configuration with annular flow;
fig. 10 is a schematic view showing a flow pattern of mist flow.
Description of reference numerals:
1. a holding tank;
2. injecting the mixture into a manifold;
3. drilling fluid;
4. simulating a riser; 19. a first simulator riser; 22. a second simulator riser;
5. simulating a drill rod;
6. simulating a shaft; 23. a first simulated sub-wellbore; 26. a second simulated sub-wellbore;
7. an on-off valve;
8. a gas manifold;
9. a manual table;
10. a gas source;
11. a first ultrasonic flow meter;
12. returning the pipe manifold;
13. a second ultrasonic flow meter;
14. a third ultrasonic flow meter;
15. a circulation pump;
16. a fourth ultrasonic flow meter;
17. a fifth ultrasonic flow meter;
18. a sixth ultrasonic flow meter;
20. a first seal member;
21. a first fixing member;
24. a second seal member;
25. a second fixing member;
27. a third seal member;
28. a gas-liquid separation device;
A. a bubble flow;
B. a bullet flow;
C. slug flow;
D. an annular flow;
E. a mist flow.
Detailed Description
The technical solutions of the present invention will be described in detail below with reference to the accompanying drawings and specific embodiments, it should be understood that these embodiments are merely illustrative of the present invention and are not intended to limit the scope of the present invention, and various equivalent modifications of the present invention by those skilled in the art after reading the present invention fall within the scope of the appended claims.
It will be understood that when an element is referred to as being "disposed on" another element, it can be directly on the other element or intervening elements may also be present. When an element is referred to as being "connected" to another element, it can be directly connected to the other element or intervening elements may also be present. The terms "vertical," "horizontal," "upper," "lower," "left," "right," and the like as used herein are for illustrative purposes only and do not denote a unique embodiment.
Unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs. The terminology used herein in the description of the present application is for the purpose of describing particular embodiments only and is not intended to be limiting of the application. As used herein, the term "and/or" includes any and all combinations of one or more of the associated listed items.
The deepwater gas invasion simulation experiment device and the deepwater gas invasion simulation experiment method provided by the invention can be used for carrying out deepwater gas invasion simulation experiments of different water depths, accurately identifying gas invasion, determining the flow mode in a shaft during gas invasion of a deepwater oil-gas field, and providing a reference for deepwater well drilling safety control.
Referring to fig. 1 to 2, a deep water gas cut simulation experiment apparatus provided in an embodiment of the present disclosure may include: a holding tank 1 for holding a drilling fluid 3; an injection manifold 2, one end of which extends into the holding tank 1; the injection manifold 2 is internally provided with an injection flow detection piece; a circulating pump 15 arranged in the injection manifold 2 for pumping out the drilling fluid 3 in the holding tank 1 for providing power; the upper end of the simulation drill rod 5 is communicated with the injection manifold 2; the simulation marine riser is characterized by comprising a simulation marine riser 4, wherein the simulation marine riser 4 is sleeved outside a simulation drill rod 5, and a first annular gap is formed between the simulation drill rod 5 and the simulation marine riser 4; the simulation well bore 6 is sleeved outside the simulation drill pipe 5, the upper end of the simulation well bore 6 is connected with the lower end of the simulation marine riser 4 in a sealing mode, a second annular gap is formed between the simulation well bore 6 and the simulation drill pipe 5, and the length of at least one of the simulation marine riser 4 and the simulation well bore 6 can be changed along the axial direction; the flow detection assembly comprises a plurality of flow meters, wherein the flow machines are at least respectively arranged close to the lower end of the simulation marine riser 4 and close to the lower end of the simulation well bore 6; and one end of the gas manifold 8 is communicated with the lower end of the simulation drill rod 5, the other end of the gas manifold 8 is connected with a gas source 10, and the gas manifold 8 is provided with a switch valve 7 and a gas flow detection piece.
In general, the deepwater gas cut simulation experiment device provided in the present specification may include: the system comprises a holding pool 1, an injection manifold 2, a pump, a simulation drill rod 5, a simulation marine riser 4, a simulation shaft 6, a flow detection assembly, a gas manifold 8 and the like. In addition, the deepwater gas cut simulation experiment device can further comprise a manual table 9, and the simulation pipe column, such as the simulation marine riser 4, can be installed on the manual table 9.
In the present embodiment, the receiving reservoir 1 is used for receiving a drilling fluid 3, which may be a hollow container. Specifically, the receiving tank 1 may be a receiving tank with an open upper end, although the receiving tank 1 may have other configurations, and the present application is not limited thereto.
In this embodiment, one end of the injection manifold 2 extends into the receiving basin 1, and the other end is in communication with the dummy drill pipe 5. The injection manifold 2 is provided with an injection flow detection piece, and the injection flow detection piece is used for acquiring the flow in the injection manifold 2.
In this embodiment, the circulation pump 15 is disposed in the injection manifold 2 and can be used to pump out the drilling fluid 3 in the holding tank 1 for power. Furthermore, when the drilling fluid 3 is returned to the drill receiving pond 1 through the return manifold 12, the drilling fluid 3 forms a circulation flow path, and the circulation pump 15 is used for providing a driving force for the drilling fluid 3 in the circulation flow path.
In the present embodiment, the upper end of the dummy drill pipe 5 communicates with the injection manifold 2; the lower end of the simulation drill pipe 5 extends into the simulation marine riser 4 and the simulation wellbore 6.
In this embodiment, the simulation marine riser 4 is sleeved outside the simulation drill rod 5, and a first annular gap is formed between the simulation drill rod 5 and the simulation marine riser 4.
The simulation riser 4 can be varied in length along the axial direction to simulate different water depths. Specifically, the pipe wall of the simulation marine riser 4 is corrugated to form a telescopic pipe.
Or, as shown in fig. 2, the simulation riser 4 may include a first simulation sub-riser 19 and a second simulation sub-riser 22 that are sleeved to each other, a first sealing member 20 is disposed at an overlapping position of the first simulation sub-riser 19 and the second simulation sub-riser 22 along the axial direction, a first fixing member 21 is disposed on the first sealing member 20, and the first simulation sub-riser 19 and the second simulation sub-riser 22 can move relatively along the axial direction.
Wherein the first simulated sub-riser 19 may be located in an upper part of the second simulated sub-riser 22 in the height direction. For example, the first simulated sub-riser 19 may be in a fixed installation and the second simulated sub-riser 22 may change the length of the simulated riser 4 when moving axially relative to the first simulated sub-riser 19. In particular, the first simulator sub riser 19 may be in the form of a fixedly mounted glass casing. The second simulator riser 22 may be in the form of a removable glass sleeve.
The first seal 20 may be a sealing rubber ring for sealing an annular gap between the first and second simulated sub-risers 19, 22. In particular, the first seal 20 may be arranged at the lower end of the first dummy riser 19 by means of a stopper.
The first fixing member 21 may be in the form of a fixing valve for fixing the second simulated sub-riser 22, the first seal member 20 on the first simulated sub-riser 19. Of course, the form of the first fixing member 21 is not limited to the above example, and the fixing valve is mainly exemplified in this specification. During adjustment, the fixed valve may be opened first, the second simulator sub riser 22 may be moved axially relative to the first simulator sub riser 19, and when the second simulator sub riser 22 is moved to the desired position, the fixed valve is closed, thereby fixing the second simulator sub riser 22, the first sealing member 20 and the first simulator sub riser 19. Wherein, this first sealing member 20 can be fixed in the lower extreme position that is close to this first simulation sub-marine riser 19, and this first mounting 21 also can be installed in the lower extreme position that is close to this first simulation sub-marine riser 19 to be convenient for utilize whole first simulation sub-marine riser 19's axial length high-efficiently, and then can adjust the different depth of water of simulation according to the length demand.
In this embodiment, the simulated wellbore 6 is sleeved outside the simulated drill pipe 5, the upper end of the simulated wellbore 6 is connected to the lower end of the simulated marine riser 4 in a sealing manner, and a second annular gap is formed between the simulated wellbore 6 and the simulated drill pipe 5.
The simulated wellbore 6 can vary in length along the axial direction. Specifically, the wall of the simulated wellbore 6 can also be corrugated to form a telescopic pipe.
Alternatively, as shown in fig. 2, the simulated wellbore 6 may include a first simulated sub wellbore 23 and a second simulated sub wellbore 26 that are connected with each other, a second sealing element 24 is disposed at an overlapping position of the first simulated sub wellbore 23 and the second simulated sub wellbore 26 along the axial direction, a second fixing element 25 is disposed on the second sealing element 24, and the first simulated sub wellbore 23 and the second simulated sub wellbore 26 can move relatively along the axial direction.
The first simulated lateral bore 23 may be located in an upper portion of the second simulated lateral bore 26 in the elevation direction. For example, the second simulated lateral wellbore 26 may be in a fixed installation, and the length of the simulated wellbore 6 may be changed when the first simulated lateral wellbore 23 moves axially relative to the first simulated lateral wellbore 23. In particular, the second simulated sub-wellbore 26 may be in the form of a fixedly installed glass casing. The first simulated sub-wellbore 23 may be in the form of a glass casing that may have been installed.
The second seal 24 may be a sealing rubber ring for sealing an annular gap between the first simulated lateral bore 23 and the second simulated lateral bore 26. Specifically, the second sealing element 24 may be disposed at the lower end of the first simulated sub-wellbore 23 through a stopper.
The second fixing element 25 may be in the form of a fixing valve for fixing the second simulated sub-wellbore 26, the first seal 20, to the first simulated sub-wellbore 23. Of course, the form of the second fixing member 25 is not limited to the above example, and the fixing valve is mainly exemplified in this specification. During adjustment, the fixed valve can be opened, the first simulated lateral wellbore 23 can be moved axially relative to the second simulated lateral wellbore 26, and when the fixed valve is moved to the position, the fixed valve is closed, so that the second simulated lateral wellbore 26, the second sealing element 24 and the first simulated lateral wellbore 23 are fixed. The second sealing element 24 can be fixed at a position close to the upper end of the second simulated sub-wellbore 26, and the second fixing element 25 can also be installed at a position close to the upper end of the second simulated sub-wellbore 26, so as to facilitate efficient utilization of the axial length of the whole second simulated sub-wellbore 26, and further adjust simulation of different well depths according to length requirements.
A third seal 27 may also be provided between the second simulator sub riser 22 and the first simulator sub wellbore 23, the third seal 27 being adapted to effect a seal between the simulator riser 4 and the simulator wellbore 6. Specifically, the third sealing element 27 may be in the form of a rubber plug, and of course, the third sealing element 27 may also be in other forms, and the application is not limited in this respect.
In one embodiment, the simulation riser 4 and the simulation wellbore 6 may be made of transparent materials to facilitate visual observation of gas invasion in the simulation riser 4 and the simulation wellbore 6.
Further, the deepwater gas cut simulation experiment device may further include: the image acquisition device comprises an image acquisition device and a controller electrically connected with the image acquisition device. The image acquisition equipment can shoot the flow conditions in the simulation marine riser 4 and the simulation shaft 6, and transmits shot data to the controller, and the controller analyzes and processes shot images.
In this embodiment, the flow rate detection module may include: a plurality of flow meters disposed at predetermined locations. Specifically, the flow meter may be in the form of an ultrasonic flow meter, but of course, the flow meter may also be in other forms, and the present application is not limited thereto. In this specification, the flow meter is mainly exemplified by an ultrasonic flow meter.
Specifically, the flow rate detection assembly may include: the ultrasonic flowmeter comprises a first ultrasonic flowmeter 11 arranged close to the lower end of the simulation marine riser 4 and a second ultrasonic flowmeter 13 arranged close to the upper end of the simulation marine riser 4; the injection flow rate detecting member provided in the injection manifold 2 is a third ultrasonic flowmeter 14; a fourth ultrasonic flow meter 16 disposed near the upper end of the simulated wellbore 6 and a fifth ultrasonic flow meter 17 disposed near the lower end of the simulated wellbore 6.
The fifth ultrasonic flow meter 17 is used to obtain a simulated downhole flow condition to obtain the earliest gas cut condition. The first ultrasonic flowmeter 11 is arranged close to the lower end of the simulated riser 4, namely the transition position of the first annular gap and the second annular gap, and is used for acquiring the flow condition at the variable cross section.
In addition, the flow detection assembly further comprises: a second ultrasonic flowmeter 13 arranged near the upper end of the simulation marine riser 4; a fourth ultrasonic flow meter 16 positioned near the upper end of the simulated wellbore 6. The second ultrasonic flowmeter 13 is configured to detect a flow rate at the top of the simulated riser 4, so as to obtain a flow rate returning out of the simulated riser 4. The fourth ultrasonic flow meter 16 is used to obtain the flow before entering the transition between the first annular gap and the second annular gap.
In the present embodiment, one end of the gas manifold 8 is communicated with the lower end of the simulation drill rod 5, and the other end is connected with a gas source 10. The gas manifold 8 is provided with a switching valve 7 and a gas flow detecting member. The switch valve 7 is used for controlling the on-off of the gas manifold 8. The gas flow rate detecting member is used for acquiring the flow rate of the gas, and the gas flow rate detecting member can also be used for detecting the flow rate of the gas under the condition that the cross section of the gas manifold 8 is constant. Specifically, the gas flow rate detecting member may be in the form of an ultrasonic flowmeter, but of course, the gas flow rate detecting member may also be in other forms. In this specification, the gas flow rate detector will be described by taking the sixth ultrasonic flow meter 18 as an example.
Further, a gas flow rate adjusting device for controlling the flow rate of the gas may be further provided in the gas manifold 8. Specifically, the gas flow rate adjusting device may be in the form of a valve having a flow adjusting function, and may be, for example, an opening-adjustable adjusting valve or the like.
In an embodiment, the deepwater gas cut simulation experiment device may further include a return manifold 12, the simulation marine riser 4 is provided with an outlet near the upper end, one end of the return manifold 12 is connected to the outlet, and the other end of the return manifold 12 is connected to the accommodating pool 1.
In this embodiment, after the return manifold 12 is provided, a circulation system may be formed among the holding tank 1, the injection manifold 2, the simulation drill pipe 5, the simulation wellbore 6, the simulation riser 4, and the return manifold 12, so as to perform a simulation experiment by recycling the drilling fluid 3 in the holding tank 1.
A gas-liquid separation device 28 may also be provided in the return manifold 12 for separating gas from the returned drilling fluid 3. Specifically, the gas-liquid separation device 28 may be disposed near the top of the holding tank 1, and when the drilling fluid 3 with entrained gas flows through the gas-liquid separation device 28, the gas-liquid separation device 28 may discharge the gas in the drilling fluid 3 to the outside, and return the liquid to the holding tank 1.
In a specific embodiment, the flow rate detection assembly includes a first ultrasonic detector for monitoring the lower end of the simulation riser 4, a second ultrasonic detector for monitoring the upper end of the simulation riser 4, a third ultrasonic detector for monitoring the flow rate of the injection manifold 2, a fourth ultrasonic detector for monitoring the upper end of the simulation shaft 6, and a fifth ultrasonic detector for monitoring the lower end of the simulation shaft 6, and the gas flow rate detector is a sixth ultrasonic detector disposed in the gas manifold 8.
In this embodiment, a total of 6 ultrasonic flowmeters are designed in the whole set of experimental apparatus for monitoring, and the following effects are achieved when 6 ultrasonic waves are respectively placed at the following positions:
the first ultrasonic flowmeter 11, as shown in fig. 1, is installed at the bottom of the riser, and when gas enters the riser from the wellbore, the cross section of the riser will suddenly become large, and the flow rate will suddenly decrease, so that the first flowmeter is installed to monitor the flow at the bottom of the riser, i.e. at the upper part of the variable cross section.
The second ultrasonic flowmeter 13, gas rises gradually in the riser, and along with the decline gradually of water pressure, the bubble will become bigger, consequently lays and monitors at monitoring riser top.
And a third ultrasonic flowmeter 14 which is arranged on a pipeline pumped into the drill pipe and monitors the flow in the drill pipe. The gas charge in the wellbore will not affect the flow in the drill pipe, since the drilling fluid 3 is pumped into the drill pipe under constant water pressure.
The fourth ultrasonic flowmeter 16, after the bottom of the shaft is filled with gas, the gas will increase gradually in the shaft, because will change suddenly at the variable cross section of the bottom of the shaft and the riser, so it has important function to set the flowmeter at the bottom of the shaft and the top of the riser compared with the former, so the flowmeter is set to monitor the flow at the top of the shaft, that is, the lower part of the variable cross section.
The fifth ultrasonic flowmeter 17, where the gas is just filled into the shaft, has no obvious change, knows the initial state of the gas invasion, and clearly compares the conditions of different depths in the later period, so that the flowmeter is arranged at the bottom of the shaft, namely the drill bit, for monitoring.
And sixthly, monitoring the flow of the gas filled in the shaft by using ultrasonic waves.
Referring to fig. 3, based on the deep water gas cut simulation experiment apparatus provided in the foregoing embodiment, the present application also provides a gas cut determination method, which may include the following steps:
firstly, the well depth and the length of a marine riser can be adjusted, and a circulating pump 15 of the drilling fluid 3 is started, so that the whole pipeline and a deep water gas invasion simulation experiment are filled with the drilling fluid 3;
after the whole pipeline and the deepwater gas invasion simulation experiment are filled with the drilling fluid 3, the gas can be filled by constant volume or constant speed.
In this specification, a constant volume of gas is first introduced as an example.
Step 10: well depth and the length of a marine riser are adjusted, and a drilling fluid 3 circulating pump 15 is started, so that the whole pipeline and a deep water gas cut simulation experiment are filled with the drilling fluid 3;
step 12: after the circulation is stabilized, recording the data of the third ultrasonic flowmeter 14, opening the switch valve 7, monitoring the sixth ultrasonic flowmeter 18, releasing a L gas, and then closing the switch valve 7;
step 14: monitoring data of the first ultrasonic flow meter 11, the second ultrasonic flow meter 13, the fourth ultrasonic flow meter 16 and the fifth ultrasonic flow meter 17;
step 16: flow based on ultrasonic flowmeter judges total overflow volume QYWhether the total overflow quantity Q is greater than or equal to a preset value (for example, 10%) or not, and when the condition is met, judging that the total overflow quantity Q is within a preset time (for example, 1 minute)YAnd if the judgment result is yes, judging that severe gas invasion has occurred at present and needing to shut down the well.
And step 17: the cycle is continued with the circulation pump 15, and the released gas is increased at an increasing rate of a L, and the above experimental steps are repeated.
In the embodiment, before the experiment, the well depth and the length of a marine riser are adjusted, and a drilling fluid 3 circulating pump 15 is started, so that the whole pipeline and a glass casing pipe simulation device are filled with the drilling fluid 3; after the cycle has stabilized, data is recorded for the third ultrasonic flow meter 14, the on/off valve 7 is opened, the flow meter is viewed, a L gas is released, and then the on/off valve 7 is closed. And observing, recording and monitoring data of the first ultrasonic flowmeter 11, the second ultrasonic flowmeter 13, the fourth ultrasonic flowmeter 16 and the fifth ultrasonic flowmeter 17, and photographing and recording the flow form in the glass sleeve in the deepwater gas invasion simulation experiment device.
In performing step 14, the method may further include: monitoring the flow form in the deepwater gas cut simulation experiment device; the flow pattern is the pattern in which the vapor phase and the liquid phase exist in a vapor-liquid two-phase flow.
According to the physical shape of the flow state, the flow in the vertical pipe flow is divided into: bubble flow a, bullet flow B, slug flow C, annular flow D, and mist flow E. The degree of gas intrusion can be judged by observing the flow pattern of the vertical pipe flow when gas intrusion occurs. Wherein, the first and second guide rollers are arranged in parallel,
as shown in fig. 6, bubble flow a: the continuous liquid phase contains a flow of dispersed vapor bubbles. Often in low mass vapor fraction regions.
As shown in fig. 7, the bullet flow B: the small bubbles coalesce into a flow of large bubbles, also called plug flow or block flow, in the shape of a bullet with dimensions close to the diameter of the channel. Is an unstable transitional flow pattern and is often found in the medium mass vapor fraction zone.
As shown in fig. 8, slug C: the gas-liquid two-phase flow state is that a section of gas column and a section of liquid column alternately appear in a pipeline.
As shown in fig. 9, the annular flow D: the liquid phase flows along the channel walls in a continuous flow in the form of an annular film, while the continuous vapor phase flows in the central part of the tube, in the liquid ring also dispersing bubbles and in the vapor phase also entraining droplets. Often in higher mass vapor fraction regions.
As shown in fig. 10, mist flow E: a flow pattern of a two-phase flow consisting of a gas and a liquid. When the gas velocity reaches a certain value in the two-phase flow, an annular flow D can be formed, most of the liquid moves in a film shape along the pipe wall at the moment, the atmospheric velocity is added on the basis of the annular flow D, the gas flows through the pipe at a high speed, and almost all the liquid is atomized, and the condition is called mist flow E.
Continuously circulating, starting a second experiment after all the gas is discharged, and releasing 2aL gas; the experiment was then performed with 3aL of gas released. The same procedure was used for experiments in which the constant rate of aeration was maintained.
Gas in the shaft fluctuates greatly when gas is injected, and fluctuation in the upper marine riser simulation device is small. When gas injection is stopped, gas in the shaft diffuses to the riser simulation device, and the shaft tends to be stable. It can be seen that the rate of change of gas in the riser simulator is also lower than in the wellbore simulator, since in the variable cross-section variation, the fluctuations are reduced as the cross-sectional area of the riser simulator increases.
The application provides a deepwater gas cut simulation experiment method corresponding to a deepwater gas cut simulation experiment device, which is characterized in that the change rule of relevant process parameters during deepwater drilling well bottom gas cut at different water depths is disclosed by judging the flow state of a drilling fluid 3 during gas cut occurrence, so that the gas cut phenomenon on a deepwater drilling site is predicted in time and in advance, and safe time allowance is provided for deepwater well control operation.
Wherein, from quantitative angle, the degree of judging the gas cut can be according to gas cut monitoring data and deep water well drilling pit shaft annular space gas-liquidThe two-phase flow model carries out inverse calculation on the gas invasion degree of the well bottom, and can calculate the gas distribution in the annular space of the well barrel at any moment after the gas invasion occurs, namely the total overflow Q at different well depthsYComprises the following steps:
QY＝AV(1-EG)△T-Q0△T
wherein A is the cross-sectional area of the annular space, m2(ii) a v is the flow rate measured in the pipe flow, measured by a third ultrasonic flow meter, m/s; egSection air void,%; Δ t is the time increment, s; q. q.s0Is the flow rate of the pump; qYThe increment of the overflow in the delta t time; rhogIs gas density, g/cm3；ρlIs liquid density, g/cm3；vlMeasuring the flow rate of the fluid by a first ultrasonic flowmeter, a second ultrasonic flowmeter, a fourth ultrasonic flowmeter and a fifth ultrasonic flowmeter, wherein m/s is the flow rate of the fluid; v. ofgMeasured by a sixth ultrasonic flow meter, m/s, is the gas flow rate.
As shown in fig. 4 and 5, the data measured when the gas intrusion test was performed using the test apparatus. FIG. 4 is a plot of cross-sectional gas void fraction versus time at various flow meters; the abscissa is time in units of S (seconds); the ordinate represents the gas content in the cross section,%.
FIG. 5 is a graph of total overflow volume versus time, with time on the abscissa and S (seconds) on the abscissa; the ordinate is the total volume of overflow in cubic meters.
In the experiment, 0S starts to inject gas into the experimental device, and gas invasion simulation is carried out. At 240S, gas injection is stopped.
In another embodiment, the gas may be charged at a constant rate after the drilling fluid 3 is charged using a simulation experiment with deep water gas cut throughout the pipeline. When the gas is filled at a constant rate, the gas intrusion determination method may include:
step 10: well depth and the length of a marine riser are adjusted, and a drilling fluid 3 circulating pump 15 is started, so that the whole pipeline and a deep water gas cut simulation experiment are filled with the drilling fluid 3;
step 11: after the circulation is stable, recording the data of the third ultrasonic flowmeter 14, opening the switch valve 7, monitoring the sixth ultrasonic flowmeter 18, and filling gas at a preset speed;
step 14: monitoring data of the first ultrasonic flow meter 11, the second ultrasonic flow meter 13, the fourth ultrasonic flow meter 16 and the fifth ultrasonic flow meter 17;
step 15: and judging whether the total overflow volume is greater than or equal to a preset value or not based on the flow of the ultrasonic flowmeter, judging whether the total overflow volume is greater than or equal to the preset value or not within a preset time when the conditions are met, and judging that gas invasion has occurred at present and the well needs to be shut down if the judgment result is yes.
Wherein the total overflow QYDetermined by the following equation:
QY＝AV(1-EG)△T-Q0△T
wherein A is the cross-sectional area of the annular space, m2(ii) a v is the flow rate measured in the pipe flow, measured by a third ultrasonic flow meter, m/s; egSection air void,%; Δ t is the time increment, s; q. q.s0Is the flow rate of the pump; qYThe increment of the overflow in the delta t time; rhogIs gas density, g/cm3；ρlIs liquid density, g/cm3；vlMeasuring the flow rate of the fluid by a first ultrasonic flowmeter, a second ultrasonic flowmeter, a fourth ultrasonic flowmeter and a fifth ultrasonic flowmeter, wherein m/s is the flow rate of the fluid; v. ofgMeasured by a sixth ultrasonic flow meter, m/s, is the gas flow rate.
The early overflow monitoring has a vital role in preventing the vicious accident of runaway blowout in the petroleum exploitation and drilling process. And gas invasion monitoring is carried out on the premise of not damaging the mechanical structure of the drilling riser in the deepwater drilling operation process. Monitoring is usually carried out at the platform mud pit, namely near the top of the marine riser, monitoring is carried out near a mud line, namely near the bottom of the marine riser along with the development of science and technology, the gas invasion degree is described, and whether gas invasion occurs or not is judged.
At present, no matter be mud pit monitoring or mud line monitoring all that the gas is invaded and has taken place a period, be difficult to judge the actual condition that takes place in the shaft bottom, consequently need the experimental apparatus urgently, invade the actual conditions that the condition counterpushed the shaft bottom stratum through the gas of judging riser and mud pit, judge the time and the degree that the gas invaded and take place. Because the gas invasion change rule of different well depths and water depths is different, the experimental device capable of adjusting the water depths and the well depths is designed to carry out related experiments.
Any numerical value recited herein includes all values from the lower value to the upper value that are incremented by one unit, provided that there is a separation of at least two units between any lower value and any higher value. For example, if it is stated that the number of a component or a value of a process variable (e.g., temperature, pressure, time, etc.) is from 1 to 90, preferably from 20 to 80, and more preferably from 30 to 70, it is intended that equivalents such as 15 to 85, 22 to 68, 43 to 51, 30 to 32 are also expressly enumerated in this specification. For values less than 1, one unit is suitably considered to be 0.0001, 0.001, 0.01, 0.1. These are only examples of what is intended to be explicitly recited, and all possible combinations of numerical values between the lowest value and the highest value that are explicitly recited in the specification in a similar manner are to be considered.
Unless otherwise indicated, all ranges include the endpoints and all numbers between the endpoints. The use of "about" or "approximately" with a range applies to both endpoints of the range. Thus, "about 20 to about 30" is intended to cover "about 20 to about 30", including at least the endpoints specified.
All articles and references disclosed, including patent applications and publications, are hereby incorporated by reference for all purposes. The term "consisting essentially of …" describing a combination shall include the identified element, ingredient, component or step as well as other elements, ingredients, components or steps that do not materially affect the basic novel characteristics of the combination. The use of the terms "comprising" or "including" to describe combinations of elements, components, or steps herein also contemplates embodiments that consist essentially of such elements, components, or steps. By using the term "may" herein, it is intended to indicate that any of the described attributes that "may" include are optional.
A plurality of elements, components, parts or steps can be provided by a single integrated element, component, part or step. Alternatively, a single integrated element, component, part or step may be divided into separate plural elements, components, parts or steps. The disclosure of "a" or "an" to describe an element, ingredient, component or step is not intended to foreclose other elements, ingredients, components or steps.
The above embodiments in the present specification are all described in a progressive manner, and the same and similar parts among the embodiments may be referred to each other, and each embodiment is described with emphasis on being different from other embodiments.
The above description is only a few embodiments of the present invention, and although the embodiments of the present invention are described above, the above description is only for the convenience of understanding the present invention, and is not intended to limit the present invention. It will be understood by those skilled in the art that various changes in form and details may be made therein without departing from the spirit and scope of the invention as defined by the appended claims.
Claims (12)
1. The utility model provides a deep water gas cut simulation experiment device which characterized in that includes:
the accommodating pool is used for accommodating drilling fluid;
an injection manifold, one end of which extends into the holding tank; a liquid injection flow detection piece is arranged in the injection manifold;
the circulating pump is arranged in the injection manifold and used for pumping out the drilling fluid in the accommodating pool to provide power;
the upper end of the simulation drill rod is communicated with the injection manifold;
the simulation marine riser is sleeved outside the simulation drill rod, and a first annular gap is formed between the simulation drill rod and the simulation marine riser;
the simulation well bore is sleeved outside the simulation drill pipe, the upper end of the simulation well bore is connected with the lower end of the simulation marine riser in a sealing mode, a second annular gap is formed between the simulation well bore and the simulation drill pipe, and the length of at least one of the simulation marine riser and the simulation well bore can be changed along the axial direction;
a flow sensing assembly comprising at least: the flow meters are arranged close to the lower end of the simulation marine riser and close to the lower end of the simulation well shaft;
and one end of the gas manifold is communicated with the lower end of the simulation drill rod, the other end of the gas manifold is connected with a gas source, and the gas manifold is provided with a switch valve and a gas flow detection piece.
2. The deepwater gas cut simulation experiment device according to claim 1, wherein the simulation riser comprises a first simulation sub-riser and a second simulation sub-riser which are sleeved with each other, a first sealing member is arranged at an overlapping position of the first simulation sub-riser and the second simulation sub-riser along the axial direction, a first fixing member is arranged on the first sealing member, and the first simulation sub-riser and the second simulation sub-riser can move relatively along the axial direction.
3. The deepwater gas cut simulation experiment device as claimed in claim 1, wherein the simulation well bore comprises a first simulation sub well bore and a second simulation sub well bore which are sleeved with each other, a second sealing element is arranged at an overlapping position of the first simulation sub well bore and the second simulation sub well bore along the axial direction, a second fixing element is arranged on the second sealing element, and the first simulation sub well bore and the second simulation sub well bore can move relatively along the axial direction.
4. The deepwater gas cut simulation experiment device of claim 1, wherein the pipe wall of the simulation riser is corrugated to form a telescopic pipe.
5. The deepwater gas cut simulation experiment device according to claim 1, wherein the simulation riser and the simulation wellbore are made of a transparent material, and the deepwater gas cut simulation experiment device further comprises: the image acquisition equipment, with image acquisition equipment electric connection's controller.
6. The deepwater gas cut simulation experiment device according to claim 1, further comprising a return manifold, wherein an outlet is provided near an upper end of the simulation riser, and one end of the return manifold is connected to the outlet and the other end of the return manifold is connected to the receiving pond; and a gas-liquid separation device is also arranged in the return manifold.
7. The deepwater gas cut simulation experiment device of claim 1, wherein the flow detection assembly comprises a first ultrasonic detector for monitoring the lower end of the simulation riser, a second ultrasonic detector for monitoring the upper end of the simulation riser, a third ultrasonic detector for monitoring the flow of the injection manifold, a fourth ultrasonic detector for monitoring the upper end of the simulation wellbore, a fifth ultrasonic detector for monitoring the lower end of the simulation wellbore, and the gas flow detector is a sixth ultrasonic detector arranged in the gas manifold.
8. A gas cut judging method using the deepwater gas cut simulation experiment device according to claim 7, wherein the method comprises the following steps:
well depth and the length of a marine riser are adjusted, and a drilling fluid circulating pump is started, so that the whole pipeline and a deep water gas cut simulation experiment are filled with drilling fluid;
after the circulation is stable, recording the data of the third ultrasonic flowmeter, opening the switch valve, monitoring the sixth ultrasonic flowmeter, releasing a L gas, and then closing the switch valve;
monitoring data of a first ultrasonic flow meter, a second ultrasonic flow meter, a fourth ultrasonic flow meter and a fifth ultrasonic flow meter;
and judging whether the total overflow volume is greater than or equal to a preset value or not based on the flow of the ultrasonic flowmeter, judging whether the total overflow volume is greater than or equal to the preset value or not within a preset time when the conditions are met, and judging that gas invasion has occurred at present and the well needs to be shut down if the judgment result is yes.
9. The gas intrusion determination method according to claim 8, wherein the total overflow Q isYDetermined by the following equation:
QY＝Av(1-Eg)△t-q0△t
wherein A is the cross-sectional area of the annular space, m2(ii) a v is the flow rate measured in the pipe flow, measured by a third ultrasonic flow meter, m/s; egSection air void,%; Δ t is the time increment, s; q. q.s0Is the flow rate of the pump; qYThe increment of the overflow in the delta t time; rhogIs gas density, g/cm3；ρlIs liquid density, g/cm3；vlMeasuring the flow rate of the fluid by a first ultrasonic flowmeter, a second ultrasonic flowmeter, a fourth ultrasonic flowmeter and a fifth ultrasonic flowmeter, wherein m/s is the flow rate of the fluid; v. ofgMeasured by a sixth ultrasonic flow meter, m/s, is the gas flow rate.
10. The gas intrusion determination method according to claim 8, the method including: when the total overflow amount is smaller than the preset value, a L is used as the increasing released gas amount, and the judgment process is repeated.
11. A gas cut judging method using the deepwater gas cut simulation experiment device according to claim 7, wherein the method comprises the following steps:
well depth and the length of a marine riser are adjusted, and a drilling fluid circulating pump is started, so that the whole pipeline and a deep water gas cut simulation experiment are filled with drilling fluid;
after the circulation is stable, recording the data of the third ultrasonic flowmeter, opening a switch valve, monitoring the sixth ultrasonic flowmeter, and filling gas at a preset speed;
monitoring data of a first ultrasonic flow meter, a second ultrasonic flow meter, a fourth ultrasonic flow meter and a fifth ultrasonic flow meter;
and judging whether the total overflow volume is greater than or equal to a preset value or not based on the flow of the ultrasonic flowmeter, judging whether the total overflow volume is greater than or equal to the preset value or not within a preset time when the conditions are met, and judging that gas invasion has occurred at present and the well needs to be shut down if the judgment result is yes.
12. The gas intrusion determination method according to claim 11, wherein the total overflow Q isYDetermined by the following equation:
QY＝Av(1-Eg)△t-q0△t
wherein A is the cross-sectional area of the annular space, m2(ii) a v is the flow rate measured in the pipe flow, measured by a third ultrasonic flow meter, m/s; egSection air void,%; Δ t is the time increment, s; q. q.s0Is the flow rate of the pump; qYThe increment of the overflow in the delta t time; rhogIs gas density, g/cm3；ρlIs liquid density, g/cm3；vlMeasuring the flow rate of the fluid by a first ultrasonic flowmeter, a second ultrasonic flowmeter, a fourth ultrasonic flowmeter and a fifth ultrasonic flowmeter, wherein m/s is the flow rate of the fluid; v. ofgMeasured by a sixth ultrasonic flow meter, m/s, is the gas flow rate.
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