MX2011008907A - Enhancer system of the flow pattern of gas wells with liquid load problems. - Google Patents
Enhancer system of the flow pattern of gas wells with liquid load problems.Info
- Publication number
- MX2011008907A MX2011008907A MX2011008907A MX2011008907A MX2011008907A MX 2011008907 A MX2011008907 A MX 2011008907A MX 2011008907 A MX2011008907 A MX 2011008907A MX 2011008907 A MX2011008907 A MX 2011008907A MX 2011008907 A MX2011008907 A MX 2011008907A
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- Prior art keywords
- flow pattern
- gas
- accordance
- flow
- well
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- 239000003623 enhancer Substances 0.000 title abstract 2
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Classifications
-
- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
- E21B43/121—Lifting well fluids
- E21B43/129—Adaptations of down-hole pump systems powered by fluid supplied from outside the borehole
Abstract
The present invention relates to an enhancer system of flow pattern applied mainly in gas-producing oil wells with liquid load problems, comprising mechanical elements that atomize the liquids accumulated at the bottom of the well facilitating their transport to surface, which is caused by the decrease of frictional pressure drops and weigh of the hydrostatic column. 1. It increases the recovery factor of well hydrocarbons, due to the reduction in the pressure requirement needed to administer the energy of the deposit; 2. It increases the lifting velocity of the produced fluids to a relatively high flow velocity of gas of 4-6 m/s; the gas expansion flows along with the condensed hydrocarbons and water, generating an uniform atomized mixture with lower density, which reduces the pressure gradient flowing in the production piping; 3. It increases the gas production, as the well production is continuous with a steady behavior even during the liquid discharge, it has a remarkable improvem ent in the flow pattern in the production piping by generating a homogenous dispersion of both phases; 4. It decreases the pressure drops along the production piping, as it is not allowed that the liquid accumulates at the bottom of the well; 5. It preserves the deposit energy due to the increase of the bottom pressure flowing; 6. It maintains the liquid production with a steady behavior caused by a improvement in the flow pattern of fluids along the production piping; and 7. It extends the flowing life of the wells as it preserves the energy in the deposit by reducing the pressure drops along the production piping.
Description
SYSTEM IMPROVING THE PATTERN OF FLOW OF WELLS OF GAS
WITH PROBLEMS OF LOADING LIQUIDS
DESCRIPTION
TECHNICAL CAMP OF THE N I NDENT
The present invention relates to a flow pattern improver system that is applied mainly in oil producing gas wells with fluid loading problems, constituted by mechanical elements that atomize the liquids accumulated in the bottom of the well, facilitating its transport towards the surface, effect caused by the decrease in pressure drops due to friction and weight of the hydrostatic column.
BACKGROUND OF THE INVENTION
The accumulation of liquids in gas wells occurs naturally due to the decrease in the energy of the deposit during its productive life, this is caused by the decrease in reservoir pressure and as a consequence of the expense that the well produces. As long as the production expense is maintained above the critical expense, the liquids will be transported to the surface and will not accumulate at the bottom of the well.
The loading of liquids in a gas well is also related to the change of flow type, the large pressure drops through the production pipeline are caused by fluctuations in the transport of gas and liquid, these fluctuations are typically called potholes. . The distribution of the liquid and gas phases flowing through a pipe simultaneously, can be classified by their shape and speed and are called flow patterns.
The parameters that influence the formation of liquid loading in a gas well are the following:
• Static reservoir pressure.
· Pressure at the head of the well.
• Pressure in the discharge line.
• Diameter of the production pipeline.
In Mexico, to solve the problem of gas field exploitation with fluid loading problems, liquid recovery systems are currently applied to extract liquids from well bottoms. The appropriate selection of these will depend mainly on the characteristics of the well, although all are directed to solve the same problem, they do not work under the same conditions; In general, the artificial production systems have a technical and temporary use range, so we will always look for the one that, for the longest time, works optimally and at the lowest cost, without being an impediment for the productive life of the well different systems are used.
The state of the art, to solve the problem of exploitation of gas fields with fluid loading problems, mainly reports the following technologies:
• Speed pipe (Small Tubing)
A speed string is a pipe of smaller diameter than that of the production pipe, this is introduced into the well with the aim of reducing the flow area to keep the expense above the critical value. Good performance has been observed in wells with low volume of production, in which, friction losses are not very significant.
The main disadvantage of this system, besides an unstable production, is that it stops working optimally in the very short term, so if it is not combined with another system it becomes a temporary solution.
Foaming Bars / Liquid Reagents (Foam Agents)
Both methods consist in the introduction of surfactants or foaming agents in the well that reduce the superficial tension of the fluids and form foam. When this happens the column of liquid becomes foam, becoming lighter and facilitating its transport to the surface; However, in spite of obtaining good results for water, in the case of condensates it has been difficult to obtain a substance that makes them foaming, so it is not convenient to apply this system in wells with water cuts of less than 80%.
This system is mainly used in wells with very low production costs due to hanging and high pressure drops along the pipelineHowever, it is not advisable to use them in wells that present emulsified liquid problems because the investment in surfactant products could be small compared to that necessary for products that break the emulsions formed. The introduction of the foam bars is carried out through the Production Pipe (TP) and the reagents are injected through a capillary pipe, they can be injected in the area of the shots or at the end of the TP.
Traveling Plunger (Plunger Lift)
Used mainly in wells with intermittent production, the traveling piston generates a mechanical interface between gas and liquid. Initially the well is closed and the plunger is on the surface and is dropped inside the TP, on its downward path the plunger allows the passage of the liquid above it preventing its return, and at the bottom the pressure generated by the The gas below the plunger increases until it coincides with the opening pressure of the motor valve of the well located on the surface. Open the well, the plunger travels along the production pipeline, dislodging the liquid pothole, then the well is closed (by motor valve indication) and the plunger falls to the bottom to start the cycle again. During its journey, this piston internally rose the pipe freeing paraffins salts carbonates etc., which could be deposited inside it.
For this system it is important that the well produces its fluids with a Gas-Oil Ratio (RGA) and sufficient pressure to lift the liquid potholes; for the case of the size of the pipe, this one can work with big sizes of this being a disadvantage in the other systems.
Compressors installed at the wellhead (Compressors)
The compression increases the speed of the gas to be equal to or greater than the critical and at the same time decreases the flowing pressure at the head of the well causing the pressure on the face of the reservoir near the well also decreases and prolongs the productive life of the well. water well.
There are many types of compressors that vary according to the initial investment, operating costs and functionality on each particular well.
Hydraulic Pumping
In this system, energy from a motor fluid is transmitted to the fluids contained in the well for extraction; a pump on the surface transmits dynamic energy to the engine fluid that is introduced into the well, where it mixes with the fluids of the well and by means of a pump in the bottom, this mixture is propelled towards the surface where it enters a separator that sends the fluids from the well outside the system and to the engine fluid back to the pump on the surface.
This system does not have a depth limit for its application and is applicable in deviated wells.
For gas wells, the pump at the bottom must be Jet type because the reciprocating pump does not admit gas and a line has to be opened to vent it. Jet pumps reduce the pressure on the face of the formation by increasing the speed of the fluid that is introduced into them.
Pneumatic Pumping (Gas Lift)
In this system gas is injected into the well at a certain depth. The gas mixes with the liquid column making it lighter, due to this, the pressure in the bottom exerted by it is reduced causing the pressure coming from the reservoir to be sufficient to push the column towards the surface.
Although it is not possible to reduce the pressure at the bottom of the well as with other pumping systems, pneumatic pumping is notable for its versatility and because of this it is a good candidate for certain conditions. While other pumping systems become inefficient for high values of Gas-Liquid Ratio (RGL), in this case a large amount of gas from the reservoir will directly decrease the volume of gas to be injected; it has no problems in handling solids and can be used in deviated wells although as these become more horizontal, gas injection does not reduce the weight of the liquid column and can increase frictional pressure losses.
Progressive Cavity Pumps
This system consists mainly of a stator with internal helix shape, double input, and a helical rotor that rotates in the stator. The cross section of the rotor is circular and in all its points eccentric to the axis; The centers of the sections are supported along a helix, whose axis is the axis of the rotor. Both are linked in such a way that the rotor section has a reciprocating movement through the stator conduit. This movement causes cavities to form, which are delimited by a line of adjustment between both elements. When the rotor is made one turn, the said cavities arranged in helical form move, including in them the liquid to be transported, said cavity being left by means of the adjustment line independent of the next to be formed, thus avoiding the return of liquid .
Although this system was originally designed to carry solids and viscous fluids, it has also been used for the extraction of liquids in gas wells; Its applicability is mainly reduced to the following general conditions:
• Depths no greater than 1, 250 meters approximately.
· Relatively high liquid expenses.
• Low pumping profile.
• Low temperatures in the well.
• Automated liquid recovery system for wells producing gas and condensate
It is based on the installation of a speed or flexible pipe string and an automated valve control system on the surface. The objective of this system is to "sweep" the accumulated liquid through a flexible pipe (or speed string and produce gas through the production pipeline); The control valves, when registering a pressure differential, act by opening or closing the system, in such a way that the fluids are produced in a continuous manner and thus avoid the intermittent production of the wells or the final closure of these.
The prior technologies known to the applicant were overcome by the present invention, since none of the cited references is integrally related to the principle of operation of the flow pattern improvement system which is applied mainly in gas producing oil wells with problems of liquid loading, since this system uses the energy of the reservoir and its fluids, to induce from the bottom of the well a change in the characteristics of the flow pattern of the liquid and gas phases, improving the transport of the liquid to the length of the production pipe, to reduce the pressure drops in the latter.
It is therefore an object of the present invention to provide a gas well flow pattern improvement system with fluid loading problems, constituted by mechanical elements that atomize the liquids accumulated at the bottom of the
well, facilitating its transport to the surface, effect caused by the decrease in pressure drops due to friction and weight of the hydrostatic column.
A further object of the present invention is to provide a flow pattern improver system that is mainly applied in oil producing gas wells with fluid loading problems.
A further object of the present invention is to provide a flow pattern improver system that is placed at the lower end of the production pipeline of the gas producing wells with liquid loading problems, to displace the liquids accumulated in the liquid to the surface. the bottom of the well.
BRIEF DESCRIPTION OF THE DRAWINGS OF THE INVENTION
Figure 1 shows external and internal views of the gas well flow pattern improving system with fluid loading problems of the present invention.
Figure 2 shows the deformation of a drop of liquid depending on the value of the Weber number.
Figure 3 shows the transition of the flow type that the gas suffers in the well as the velocity of the gas decreases.
Figure 4 shows a diagram of the secondary expander of the present invention.
Figure 5 shows the behavior of the pressure gradient and productions of the Cuitlahuac-802 well of the Burgos Integral Asset, with and without the use of the gas well flow pattern improvement system with fluid loading problems of the present invention.
DETAILED DESCRIPTION OF THE INVENTION
The present invention relates to a flow pattern improver system that is applied mainly in oil producing gas wells with fluid loading problems, constituted by mechanical elements that atomize the liquids accumulated in the bottom of the well, facilitating its transport towards the surface, effect caused by the decrease in pressure drops due to friction and weight of the hydrostatic column.
Figure 1 shows external and internal views of the gas well flow pattern improvement system with fluid loading problems of the present invention, which is constituted by five mechanical elements (subsystems):
1) Primary expander. It is the first mechanical element, it allows the expansion of the gas stream coming from the well that is the driving fluid up to a state of high speed; that is, it has the function of causing the first pressure drop through a controlled restriction of flow, generating the expansion of gas coming from the well, which is the driving fluid to a state of high speed, caused by the pressure energy of the reservoir, the sudden expansion of gas increases the speed that in the presence of liquid, promotes the formation of a homogeneous mixture.
2) Homogenization chamber. It is the second mechanical element and is connected to the primary Expander, in its interior the stabilization and homogenization of the gas and liquid flow coming from the first expansion stage is carried out, and the fluids are transported through the Chamber to the third element Mechanical called secondary expander; that is, it has an inner diameter greater than that of the primary Expander and is connected to the primary Expander in the lower part and to the secondary Expander in the upper part, in its interior the stabilization and homogenization of the gas and liquid flow coming from the First stage of expansion, the fluids are transported through the Chamber to the secondary expander.
) Secondary expander. It is the third mechanical element and is coupled to the homogenization chamber, having the function to cause a second restriction to the flow, has a geometry such that increases the speed of the gas, forming areas of low pressure in its interior, where it lodges the Veins of suction; in the upper part it has a fishing neck, which is the geometry that allows the installation and removal of the improvement system of the flow pattern inside the production pipeline.
) Suction veins. They are the fourth mechanical element, they are housed in the low pressure zones inside the secondary expander and communicate the low pressure zones inside the secondary expander with the liquid accumulated on the outside of the system, they have the function of allowing the liquid accumulated on the outside of the system is sucked by the gas stream (motive fluid) decreasing the liquid particle size (atomization process) using the high velocity of the gas stream reached in the secondary expander in the low pressure zones.
) Anchoring system and hermeticity. It is the fifth mechanical element, it is coupled in its inner part to the primary expander and homogenization chamber and at its upper end to the secondary expander, and allows to install the flow pattern improver system in any depth of the well production pipeline and At the same time it forces the flow to be carried out only inside all the aforementioned elements, it has mechanical anchors that are fixed to the pipe and elastomer seals that allow anchoring the system and cause airtightness on its exterior so that the flow is performed entirely in its interior as mentioned above.
According to the above, the gas well flow pattern improvement system with fluid loading problems of the present invention is installed at the lower end of the production pipeline and has the function of causing an increase in the speed of the fluids passing through two restrictions in the interior of the system, this causes expansion of gas that flows together with the condensates and / or water, this process allows to obtain a gas / condensate / uniform water mixture (atomization of liquids in the gas) which avoids the slippage of the gas and the problems of pitch, in addition a minimum back pressure is maintained on the face of the formation and reduces the pressure drops due to friction.
The flow pattern improving system of the present invention can be placed below the depth at which the bubbling pressure is obtained and is very useful when handling high dissolved gas / oil ratios, since in this case the amount Additional released gas helps to "drag" liquids accumulated in the bottom of the well to the surface, without the requirement of an external energy source.
The flow pattern improving system of the present invention utilizes the latent energy in the dissolved gas, upon release and expansion to elevate the fluids accumulated in the well; When the gas velocity is lower than the minimum drag velocity, there will be liquid runoff to the bottom of the well through the walls of the production pipeline, when this happens the liquids are reincorporated into the high velocity gas stream when they are introduced to the body of the secondary expander via suction veins, that is, areas of low pressure that in turn fractionate, distribute and atomize the liquids in the gas stream.
The flow pattern improving system of the present invention is based on the principle of conservation of the momentum of the fluid streams involved (gas, condensed hydrocarbons and / or water). The flow pattern improving system of the present invention is based on the transmission of energy by impact of a fluid at high velocity (gas), against another fluid in motion or at rest (condensates and / or water), to provide a mixture of fluid at a moderately high velocity, which then decreases until a final pressure greater than the initial one of the lower velocity fluid is obtained.
The flow pattern improving system of the present invention as a whole, promotes the expansion of gas at the bottom of the well by increasing its speed to that necessary to incorporate the existing liquids in atomized form through the production pipeline to the surface, This term is known as critical velocity, in this regime liquid droplets move within the gas stream being subjected to the drag and gravity forces, fragmenting the liquid particles by the effects of the incorporation through the veins of suction and secondary expander, while the surface tension of the liquid acts to prevent its fragmentation (surface pressure). The antagonism of the two pressures determines the maximum measure that a drop can achieve, being represented as follows:
Speed pressure: vG2p6
Surface pressure: s / d
where:
vc: Speed with which the drop of liquid moves in the gas.
pc: Gas density.
s: Surface tension of the liquid drop.
d: Diameter of the drop of liquid.
These two pressures integrate the Weber number (We) which is a dimensionless number and which is useful in the analysis of flows where there is a surface between two different fluids.
We = v- ^ (1)
If this number exceeds the critical value, the drop of liquid will be fragmented, the critical value for the free fall of a drop is between 20 and 30.
With a Weber number within the critical range, the deformation of the drops of the liquids at high velocities of the gas stream is considered a spherical figure; If the Weber number is less than 20 or greater than 30, there will be a pressure difference in the sides of the liquid drop causing it to deform, which is clearly seen in Figure 2.
The total force of gravity is represented by the following equation:
Fa = fc pi - PG ^ (2)
and the total drag force is given by:
Fi = Íg-cPGCaA. { v6 -v 2 (3) where:
g: Gravitational constant.
d: Diameter of the drop of liquid.
pL: Density of the liquid.
pc: Gas density.
Ca: Coefficient of drag.
A. Area of the cross section of the drop of liquid.
vG: Gas velocity.
vL Speed of liquid drop.
The critical velocity of the gas to transport the drop of liquid from the bottom of the well is defined as the rate at which the drop will be suspended in the gas stream. Therefore, the critical velocity of the gas vc is the velocity at which vL = 0, if the velocity of the liquid drop is zero, the net force in it is also zero. The equation that defines the concept of critical speed is the following:
Fa = Fd (4)
Substituting the values of both forces:
(5)
Rewriting the area A = p? 2/4 and solving for vc, you get:
This equation considers a known liquid droplet diameter. Actually, the diameter of the liquid drop depends on the gas velocity, but the Weber number can be obtained.
Equalizing Weber's number to 30, substituting vG for vc and clearing d:
Substituting this equation in Equation 6:
Considering a drag coefficient Ca of 0.44, which corresponds to the value used for a completely turbulent flow. Substituting the drag coefficient for turbulent flow and the values of g and ge, the following is obtained:
vc = 17. 514 (^^ < r) 1 4 (10)
where:
pL: Density of the liquid, (lbm / ft3).
pc: Gas density, lbm / ft3).
s: Surface tension, (ibf / foot).
vc: Critical gas velocity, (ft / s).
If you want to use the surface tension in units of dyne / cm, using the conversion (. & // p) = 0.00006852 (day / cm) you get:
c = 1,593 (¾pa) (11)
Where all the variables hold the units of Equation 10 except o.
Once the critical gas velocity is known, the critical expense can be calculated which turns out to be a more practical value due to its applicability:
where:
A: Cross section of the interior of the production pipeline, (pie2).
p: Pressure at the head of the well, (lb / pg2).
T: Temperature at the well head, (° F).
qc: Gas critical expense, (mmpie3 / díd).
Predictions of the critical velocity of wells with low head well pressures are more uncertain.
There are two versions of correlations, one for water and the other for condensed hydrocarbons:
. . ..
- 402 (45-0.0031p) 1 ^
eg, count-count (0.0031p) 1/2 '' where:
p: Fluid pressure at the head of the well, (lb / pg2).
vg: critical gas velocity, ft / s).
The coefficients of 5.321 and 4.043 respectively for water and condensed hydrocarbons respectively can be considered. In addition to the critical speed correlation, obtaining for the critical gas expense as follows:
_ 0.0676pdt2 (45- 0.0031p) V *. . .
QCgas + water - (T + 460) z (0.0031P) 1/2 ^ b '
_ 0.0890pdt2 (67-0.0031P) 1/4
QCgas + condensed hcs ~ (r + 460) z (0.003 lp) 1 ^ (16)
As long as the cost of the fluids in a well remains above the critical expense, there will be no column formation of liquids in the bottom of the well.
Figure 3 shows the transition of the flow type that the gas suffers in the well as the velocity of the gas decreases.
Based on the foregoing, it can be established that the flow pattern improving system of the present invention increases the velocity of the gas by promoting the atomization of the liquids, with a relatively high gas flow rate of 4-6 m / s, reaching fog flow and a continuous flow structure (in the continuous gas phase there are scattered liquid droplets). The gas expenditure is sufficient to lift the liquid (water and condensate) to the surface. If the liquid droplets flow in the same direction as the gas, there is a mist flow structure and if the liquid droplets flow with turbulence it can be called an atomized or foaming structure.
The secondary expander, illustrated by a diagram in Figure 4, includes the inlet section of the liquid stream; in this chamber it is dragged by the motive fluid (gas at high speed). The mixing chamber allows intimate mixing between the motor and entrained fluids.
The calculations for the design, consider three different processes: expansion, compression and mixing, so there are specific methods for each type of element, which consist mainly in determining the flow areas and their geometry. Once the equipment has been designed, it must operate at the stationary conditions for which it was designed and the fundamental calculation is that of the drag coefficient:
Drag coefficient = Motor flow / Dragged flow
Based on the foregoing, the gas well flow pattern improvement system with fluid loading problems of the present invention solves the problems caused by the accumulation of liquids at the bottom of the wells, taking advantage of the same energy of the gas produced to "sweep" the accumulated liquid, in such a way that the fluids are produced in a continuous way and thus avoid the intermittent production of the wells or the final closure of these, prolonging the flowing life of the same and thereby increasing the recovery factor reflected in the incorporation of gas reserves that allow greater energy resources.
The flow pattern improving system of the present invention, mainly provides the following associated benefits:
a) Increase the hydrocarbon recovery factor in wells, due to the reduction in the pressure requirement necessary to administer the reservoir energy;
b) Increase the speed of elevation of the produced fluids, at a relatively high gas flow rate of 4-6 m / s; the expansion of the gas flows together with the condensed hydrocarbons and the water, generating a uniform atomized mixture with lower density, which reduces the gradient of flowing pressure in the production pipeline;
c) Increase gas production, since the production of the well is continuous with a stable behavior even during the discharge of liquid, it has a remarkable improvement in the flow pattern in the production pipeline by generating a homogeneous dispersion of both phases;
d) It decreases the pressure drops along the production pipe, since it does not allow the liquid to accumulate in the bottom of the well;
e) It conserves the energy of the deposit due to the increase of the bottom pressure flowing;
f) Maintains liquid production with a stable behavior, caused by an improvement in the flow pattern of the fluids along the production pipeline; Y
g) It prolongs the flowing life of the wells, since it conserves the energy in the deposit thanks to the decrease of the pressure drops along the production pipeline.
Next, a practical example of the present invention is described to have a better understanding of it, without this limiting its scope.
EXAMPLE
The application of the gas well flow pattern improvement system with fluid loading problems of the present invention was carried out in the Cuitlahuac-802 well of the Burgos Integral Asset, in this well the accumulation of liquids is a generalized problem in the Cuitlahuac field due to its conditions of pressure, production and composition of the fluids it produces.
The activities carried out for the installation of the flow pattern improving system of the present invention consisted of:
1) Well selection. To carry out the selection of the well, those wells that had sufficient information to perform a simulation of the behavior of the flow pattern improver were identified, in addition to identifying that they did not have another system installed to block the production pipeline.
2) Simulation of the production conditions of the well. The simulation supported on a finite element was carried out, in order to determine the production conditions of the well and determine the optimum installation depth, as well as the diameters of the flow restrictions, both upper and lower.
Design and manufacture of the flow pattern improvement system. The appropriate flow pattern improver system was designed and manufactured for the conditions of pressure, temperature, depth and properties of the fluids produced by the well.
Technical specifications of the flow pattern improvement system for the Cuitlahuac-802 well of the Burgos Integral Asset:
a) 7,000 psi operating differential pressure.
b) Maximum working pressure of 11,000 psi.
c) Maximum operating temperature 177 ° C.
d) Installed and released with steel line.
e) Interchangeable and easy maintenance components.
f) Interior generator of a hermetic seal to avoid leaks.
g) Maximum diameter of 2,250 inches.
h) Length of 2.10 meters.
i) System applicable to deviated wells up to 35 ° (3o per 100 meters), j) Resists aggressive environments, with the presence of CO2 and H2S.
k) Primary expander, homogenization chamber and secondary expander manufactured in 4140 steel treated with surface coating with a hardness of 97 RwC.
Installation of the flow pattern improvement system. The installation of the flow pattern improver system was performed, as follows:
The flow pattern improver system is installed at the end of the production pipe, it is introduced into the well through a steel line unit by means of a JDC release tool, called a davit; once the installation depth is reached, it is anchored in the production pipeline by means of sudden descending movements with a mechanical scissors and weight bars; the tightness of the system is obtained by hitting the upper part of the system with a blind box. The sequence of operations to recover the system is done by hitting up with mechanical scissors and weight bars until it is released.
) Obtaining Results. The behavior of the pressure gradient and productions of the Cuitlahuac-802 well of the Burgos Integral Asset are shown in Figure 5, which is complemented by the following results:
a) The flow pattern improvement system increased gas production by more than 300%, with respect to the initial production: from 0.315 to 1.08 million cubic feet of gas per day;
b) The production of the well is continuous and had a stable behavior even during the discharge of liquid;
c) There was a notable improvement in the flow pattern in the production pipeline, generating a homogeneous dispersion of both phases, the water cut was reduced;
d) Decreased pressure drops along the Production Pipeline (TP), since it did not allow the liquid to accumulate in the bottom of the well;
e) The energy of the reservoir was conserved due to the increase of the bottom pressure flowing, as was the case of operation in the high pressure discharge line;
f) The anchoring operation of the flow pattern improvement system was successful. The response of the well, monitored on the surface with three-phase measuring equipment, allowed observing that the well was stabilized with a higher than normal gas production, due to the application of the flow pattern improvement system; Likewise, the production of liquid had a more stable behavior, caused by an improvement in the flow pattern. g) The flow pattern improvement system can be used to prolong the flowing life of the wells, since it conserves the energy in the deposit thanks to the decrease of the pressure drops along the production pipeline, which was identified by the background pressure record flowing taken 2 hours after installation.
h) It avoids the formation of hydrates, since the head temperature increases to 45 ° C, due to the expansion and heating of the gas that causes the improvement system of the flow pattern located at 2,000 m.
i) Additionally, the flow pattern improvement system prevents the repression of surface lines due to the accumulation of methane hydrates, which reduce the flow area to the battery, causing the low production of gas, especially in the winter season.
Claims (21)
1. A gas well flow pattern improvement system with fluid loading problems, comprising the following elements: a) Primary expander, b) Homogenization chamber, c) Secondary expander, d) Suction veins, and e) Anchoring and sealing system, to move to the surface the liquids accumulated in the bottom of the well, taking advantage of the same energy of the gas produced, prolonging the flowing life of the wells continuously and increasing its recovery factor.
2. The flow pattern improver system of claim 1, which is preferably applied in oil producing gas wells with fluid loading problems.
3. A system for improving the flow pattern in accordance with the preceding claims, where the primary expander has a smaller internal diameter than the homogenization chamber.
4. A flow pattern improver system in accordance with the preceding claims, where the primary expander is connected to the bottom of the homogenization chamber.
5. A flow pattern improvement system in accordance with the preceding claims, wherein the homogenization chamber is connected to the primary expander in the lower part and to the secondary expander in the upper part.
6. A flow pattern improvement system in accordance with the preceding claims, where the secondary expander is coupled to the homogenization chamber in the upper part of the homogenization chamber.
7. A flow pattern improver system in accordance with the preceding claims, where the secondary expander accommodates the suction veins.
8. A flow pattern improvement system in accordance with the preceding claims, where the secondary expander at the top has a fishing neck.
9. A flow pattern improver system in accordance with the preceding claims, where the suction veins are housed in the low pressure zones of the interior of the secondary expander and communicate the low pressure zones of the interior of the secondary expander with the liquid accumulated in them. the outside of the system.
10. An improvement system of the flow pattern according to the preceding claims, where the anchoring and sealing system is coupled in its inner part to the primary expander and homogenization chamber and at its upper end to the secondary expander.
11. A flow pattern improver system in accordance with the previous claims, where the anchoring and sealing system allows to install the flow pattern improver system in any depth of the well production pipeline.
12. A system for improving the flow pattern in accordance with the preceding claims, where the anchoring and sealing system requires that the flow be carried out only inside the flow pattern improving system.
13. An improvement system of the flow pattern in accordance with the previous claims, where the anchoring and sealing system has mechanical anchors that are fixed to the pipe and elastomer seals that allow anchoring the system and cause airtightness on the outside so that the flow is carried out in its entirety inside.
14. A flow pattern improver system in accordance with the preceding claims, wherein the flow pattern improver system is installed at the lower end of the production pipeline.
15. A flow pattern improving system according to the preceding claims, wherein the flow pattern improving system can be located below the depth at which the bubbling pressure is present.
16. A flow pattern improvement system in accordance with the preceding claims, where the gas velocity is increased by promoting the atomization of the liquids, with a relatively high gas flow rate of 4-6 m / s, reaching mist flow and a continuous flow structure (in the continuous gas phase there are scattered liquid drops).
17. An improvement system of the flow pattern in accordance with the previous claims, where the calculations for the design of each element, consider three different processes: expansion, compression and mixing, and are carried out through specific methods, which consist fundamentally in determining the flow areas and their geometry.
18. A flow pattern improvement system in accordance with the preceding claims, where the drag coefficient is determined by the formula: Drag coefficient = Motor flow / Dragged flow
19. A flow pattern improvement system in accordance with the preceding claims, where the flow pattern improvement system increased gas production by more than 300%, with respect to initial production.
20. A flow pattern improver system in accordance with the preceding claims, wherein the flow pattern improver system prevents the formation of hydrates.
21. A flow pattern improver system in accordance with the preceding claims, where the flow pattern improving system prevents the repression of surface lines by accumulation of methane hydrates.
Priority Applications (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| MX2011008907A MX2011008907A (en) | 2011-08-24 | 2011-08-24 | Enhancer system of the flow pattern of gas wells with liquid load problems. |
| US13/590,658 US20130048293A1 (en) | 2011-08-24 | 2012-08-21 | Flow pattern enhancer system for gas wells with liquid load problems |
| CA2787617A CA2787617A1 (en) | 2011-08-24 | 2012-08-23 | Enhancer system of the flow pattern of gas wells with liquid load problems |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| MX2011008907A MX2011008907A (en) | 2011-08-24 | 2011-08-24 | Enhancer system of the flow pattern of gas wells with liquid load problems. |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| MX2011008907A true MX2011008907A (en) | 2013-02-25 |
Family
ID=47741966
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| MX2011008907A MX2011008907A (en) | 2011-08-24 | 2011-08-24 | Enhancer system of the flow pattern of gas wells with liquid load problems. |
Country Status (3)
| Country | Link |
|---|---|
| US (1) | US20130048293A1 (en) |
| CA (1) | CA2787617A1 (en) |
| MX (1) | MX2011008907A (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2020046105A1 (en) * | 2018-08-30 | 2020-03-05 | Instituto Mexicano Del Petróleo | Device for the bottom of hydrocarbon-producing wells lacking conventional production tubing |
Families Citing this family (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103867184B (en) * | 2014-02-10 | 2016-11-09 | 中国石油天然气股份有限公司 | A kind of gas well critical liquid carrying flow rate determines method and device |
| WO2015126648A1 (en) * | 2014-02-24 | 2015-08-27 | Exxonmobil Upstream Research Company | Gas well deliquification by liquid entrainment |
| CN104612659B (en) * | 2015-02-10 | 2017-03-15 | 中国地质大学（武汉） | A kind of determination method of the critical liquid carry over of low gas liquid rate gas well |
| CN106525190B (en) * | 2016-12-30 | 2019-05-03 | 山东精工电子科技有限公司 | The device scale method of detection cylinder lithium ion battery gas production |
| US11021933B1 (en) | 2017-09-13 | 2021-06-01 | David A. Webb | Well hole cleaning tool |
| CN113073962A (en) * | 2020-01-06 | 2021-07-06 | 西南石油大学 | Axial turbine lifting device |
| CN113818835B (en) * | 2021-08-29 | 2023-07-14 | 西南石油大学 | Reflux inflow control valve |
Family Cites Families (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US5893414A (en) * | 1998-05-02 | 1999-04-13 | Petroenergy Llc | Device for intensification of hydrocarbon production and hydrocarbons production system |
| CA2338730A1 (en) * | 1998-07-21 | 2000-02-03 | Dmitry Dveyrin | Method and apparatus for conveying fluids, particularly useful with respect to oil wells |
| US7051817B2 (en) * | 2004-08-09 | 2006-05-30 | Sorowell Production Services Llc | Device for improving oil and gas recovery in wells |
| US8100184B2 (en) * | 2005-07-20 | 2012-01-24 | University Of Southern California | Collection and lift modules for use in a wellbore |
| WO2009014155A1 (en) * | 2007-07-25 | 2009-01-29 | Semiconductor Energy Laboratory Co., Ltd. | Photoelectric conversion device and electronic device having the same |
-
2011
- 2011-08-24 MX MX2011008907A patent/MX2011008907A/en not_active Application Discontinuation
-
2012
- 2012-08-21 US US13/590,658 patent/US20130048293A1/en not_active Abandoned
- 2012-08-23 CA CA2787617A patent/CA2787617A1/en not_active Abandoned
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2020046105A1 (en) * | 2018-08-30 | 2020-03-05 | Instituto Mexicano Del Petróleo | Device for the bottom of hydrocarbon-producing wells lacking conventional production tubing |
Also Published As
| Publication number | Publication date |
|---|---|
| US20130048293A1 (en) | 2013-02-28 |
| CA2787617A1 (en) | 2013-02-24 |
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