CN113357167B - Electrical submersible pump well abnormity diagnosis method based on double-suppressed pressure curve - Google Patents
Electrical submersible pump well abnormity diagnosis method based on double-suppressed pressure curve Download PDFInfo
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04D—NON-POSITIVE-DISPLACEMENT PUMPS
- F04D15/00—Control, e.g. regulation, of pumps, pumping installations or systems
- F04D15/02—Stopping of pumps, or operating valves, on occurrence of unwanted conditions
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04D—NON-POSITIVE-DISPLACEMENT PUMPS
- F04D13/00—Pumping installations or systems
- F04D13/02—Units comprising pumps and their driving means
- F04D13/06—Units comprising pumps and their driving means the pump being electrically driven
- F04D13/08—Units comprising pumps and their driving means the pump being electrically driven for submerged use
- F04D13/10—Units comprising pumps and their driving means the pump being electrically driven for submerged use adapted for use in mining bore holes
Abstract
The invention discloses an electrical submersible pump well abnormity diagnosis method based on double pressure holding curves, which quantitatively reflects the pumping efficiency of an underground unit and deduces a quick diagnosis formula through an interpretation method of the two pressure holding curves, so that a front-line worker can quickly judge the running state of an underground electric pump, and further, the operation decision of an oil well is assisted.
Description
Technical Field
The invention belongs to the technical field of petroleum engineering machinery, and particularly relates to an electrical submersible pump well abnormity diagnosis method based on a double-suppressed pressure curve.
Background
In the daily well management of the electric submersible pump, the underground working condition of the electric submersible pump needs to be judged. The current card of the electric pump well can not effectively judge the faults of electric pump or pipe column leakage, pump lifting capacity reduction, low pump efficiency and the like. Aiming at the problem, a wellhead pressure holding (wellhead closing without pump stopping) diagnosis process and a method of the wellhead pressure holding are provided. The pump condition is qualitatively explained by using the pressure-holding curve, and the pressure curve is measured by closing the valve to hold pressure in the running state and the shutdown state respectively. Based on the fluid pressure transmission theory, the measured curve is qualitatively analyzed according to various pressure change rules reflected by different pump conditions during pumping so as to reflect various working conditions of the pump.
The pressure building diagnosis technology of the mechanical production well is widely applied to a plurality of oil fields at home and abroad, has good application effect, and has a plurality of research results aiming at the understanding of the mechanism after the mechanical production well is shut in. The method specifically comprises the steps of theoretically analyzing the change relation between the pressure building value and time of the submersible electric pump well according to the working principle of the submersible electric pump and the seepage mechanics theory, establishing a mathematical model of the pressure building curve of the submersible electric pump well, and drawing typical pressure building characteristic curves under different working conditions. In the production process of the submersible electric pump well, the pump efficiency is reduced due to a plurality of factors such as pipe column leakage, high production gas-oil ratio, emulsification or pump shaft fracture, and the development effect of the production well is poor. In addition, the ideal pressure build-up curve requires that the model meets the condition that the liquid pumping amount in each stage is the mean value, and the dynamic pressure build-up curve is the result of superposition of the three stages. In a pressure build-up test in the actual field, after closing the gate, the recorder usually records the wellhead pressure value every 15 s. In the pressure holding-down process, the pressure in the second stage rises quickly, high wellhead pressure can be achieved in a short time, and the interval point of the acquisition time is long, so that each pressure holding-down stage on the curve is difficult to divide. In the high-discharge high-water-content well, the space occupied by gas is small, the liquid pumping amount per second is large, the pressure rises quickly, and the curve shows a logarithmic relation of a third stage in the whole course. In the high-gas-production well, the log relation stage is usually started without observing a straight line segment, and a curve shows a step-like rise. A new theoretical method is needed to explain the pumping efficiency of the current pressure holding curve.
Disclosure of Invention
The method aims to solve the problem that a single pressure building curve measured for diagnosing the abnormality of the electric submersible pump well has a large artificial explanation factor in the actual production process and solve the problem of low efficiency of misjudgment of the electric pump caused by insufficient liquid supply. The invention provides an electrical submersible pump well abnormity diagnosis method based on a double-suppressed pressure curve.
The invention is realized by the following technical scheme:
an electrical submersible pump well abnormity diagnosis method based on a double-suppressed pressure curve comprises the following steps:
firstly, closing a well mouth, not closing an underground electric pump unit, recording a pressure value of the well mouth, ending the test 2-3 minutes after the pressure value of the well mouth reaches the maximum value, replying the production of the well mouth, and measuring a first well mouth pressure building curve without fluid infusion;
step two, stopping the well, and performing fluid infusion operation on the well, wherein the required shortest fluid infusion time is described by the following formula:
t＝πr2(hseq-hbot)/q+tmax
wherein r is the diameter of a casing, hseq is the slant depth of a unit separator, hbot is the slant depth of the middle depth of an oil reservoir, tmax is the predicted pressure holding time, and q is the fluid infusion amount;
standing for a period of time, repeating the step one, and measuring a wellhead pressure building curve after second fluid infusion;
step three, establishing a pressure building model aiming at the abnormal operation state of the electric pump caused by low unit efficiency due to emulsification, blade abrasion, pump shaft breakage and the like:
the pressure building process before water supplement is divided into three stages:
1) a gas compression stage: after the pressure is suppressed, more free gas exists in the oil pipe, and the compressed gas is mainly used in the initial pressure-suppressed stage because the gas compression coefficient is far greater than the liquid compression coefficient;
2) a liquid compression stage: after the pressure rises to a certain degree, the volume of the gas is small, at the moment, the curve reflects the compression property of the liquid, and the pressure and the time are in a linear relation;
3) and (3) a synchronization recovery phase: when the pressure continues to rise, the lift of the electric pump reaches the maximum, the pump is not filled with liquid at the stage, the wellhead pressure and the bottom hole flowing pressure are synchronously recovered, and the pressure and the time are in logarithmic relation similarly to the well closing pressure recovery stage;
and (3) establishing a piecewise function model of pressure and time by segmenting the curve, and obtaining the following formula (1):
wherein P is0Initial oil pressure, MPa; clIs the liquid compressibility; vp is the liquid pumping amount, m3(ii) a Vg is the gas volume at time t, m3(ii) a Vt is the oil pipe liquid volume, m3(ii) a q is formation production, m3U is viscosity, mPa.s; and B is the volume coefficient of the fluid. K is permeability 10-3um2. P1 is the pressure at the end of the first stage, P2 is the pressure at the end of the second stage;
and after annular fluid infusion is carried out on the well, according to the dynamic rule of production, the produced fluid is high in water content at the initial stage after fluid infusion. Comparing the well condition after water supplement with the well condition after water supplement approximately to a pure water producing stage, and changing a pressure building model after the water supplement into:
wherein P is0As initial oil pressure, ClThe liquid compression factor is Vp, the liquid pumping amount is Vg, the gas volume at the time t is Vg, the liquid volume of the oil pipe is Vt, and P1 is the pressure at the end of the first stage.
Drawing a pressure building derivative curve, determining phase conversion points, carrying out derivation operation on the pressure building curve, constructing the pressure building derivative curve through discrete points, making a straight line with the value of the slope of the initial straight line segment after liquid supplement in a pressure building pressure derivative diagram because the second phase before liquid supplement corresponds to the first phase after liquid supplement and the slope difference between the two phases is small, and making an intersection point corresponding to the abscissa t1And t2Two moments are taken as two stage conversion points, namely a liquid compression point and a pressure synchronous recovery point.
Determining time and pressure corresponding to the stage conversion point, particularly a pressure synchronous recovery point, and calculating the efficiency of the underground electric pump; the characteristic curve of the head and the displacement of the electric submersible pump before and after fluid infusion is made by using a clear water medium, and can be regressed into the following relation:
H＝c-aq2-bq (3)
before annulus fluid infusion, when the pressure reaches a synchronous recovery point in the pressure building process, namely when the compression stage of the mixed fluid is shifted to a logarithmic relation stage, the pumping liquid flow of the electric pump is 0, and the lift of the electric pump reaches the maximum at the moment. According to the pressure balance, the following conditions are satisfied:
wherein: p is wellhead oil pressure in MPa; l is the height of the liquid level of the oil pipe, m; eta 1 is the pump efficiency under the well condition, Hmax is the maximum lift of the characteristic curve, m; r is a radical of hydrogenmIs the oil pipe liquid weight N/m3；
Is the average weight N/m of the mixture in the pump3(ii) a Pin is the pump inlet pressure, MPa.
rmThis can be obtained by the following equation:
in the formula: rs is the gas-oil ratio (the interior of an oil pipe needs to be corrected according to the dissolved gas-oil ratio), fw is the water content, Pa is the atmospheric pressure, and ro is the specific gravity of the oil.
After the annular fluid infusion, the pressure of the pump inlet can be deduced according to the formulas (3) and (4) that the pressure of the pump suction inlet is as follows:
Pinw＝P0+Lrw-η2rw(c-aq2-bq) (6)
in the formula: p0 is oil pressure before pressure holding, q is liquid production amount before pressure holding, L is oil pipe liquid level height, rwThe specific gravity of water, eta 2 is the efficiency of the electric pump unit, and the simultaneous formulas (4) and (6) are as follows: efficiency of electric pump under pressure build-up with clear water:
the viscous lift coefficient a is eta 1/eta 2, which reflects the influence of fluid viscosity on the pump efficiency, eta 1 reflects the pump efficiency under the well condition, and eta 2 reflects the loss of the electric pump (impeller abrasion, pump breakage and the like). The underground working state of the directional diagnosis electric pump well is obtained through the three parameters, and an effective basis is provided for the formulation of the implementation of next measures.
The invention has the advantages and beneficial effects that:
the invention discloses an electrical submersible pump well abnormity diagnosis method based on double pressure holding curves, which quantitatively reflects the pumping efficiency of an underground unit and deduces a quick diagnosis formula through an interpretation method of the two pressure holding curves, so that a front-line worker can quickly judge the running state of an underground electric pump, and further, the operation decision of an oil well is assisted.
Drawings
Fig. 1 is a pressure build-up curve under different well conditions in an embodiment of the present invention.
Fig. 2 is a diagram of a pressure building curve before and after annulus fluid infusion in an embodiment of the invention.
Fig. 3 is an ideal pressure build-up derivative pressure curve constructed in an embodiment of the present invention.
Fig. 4 is a pressure-building pressure derivative curve constructed by data collected on site in the embodiment of the present invention.
For a person skilled in the art, without inventive effort, other relevant figures can be derived from the above figures.
Detailed Description
In order to make the technical solution of the present invention better understood, the technical solution of the present invention is further described below with reference to specific examples.
Example 1:
step 1) in an actual field pressure holding test, firstly closing a wellhead, but not closing an underground electric pump unit, simultaneously recording a wellhead pressure value by a recorder, usually recording the wellhead pressure value every 15s, but in view of the large discharge capacity of the current unit, measuring the wellhead pressure value once within 0.5-1 second is recommended, and when the wellhead pressure value reaches the maximum value, measuring the wellhead pressure holding curve 2-3 minutes, ending the test, returning to wellhead production, and measuring the first wellhead pressure holding curve without liquid supplement.
And 2) stopping the well, and performing fluid replacement operation on the well. The concrete required shortest fluid infusion time can refer to the formula: t ═ π r2(hseq-hbot)/q+tmax
Wherein r is the diameter of a casing of a dead well, hseq is the inclined depth of a unit separator, hbot is the inclined depth in an oil reservoir, tmax is the predicted pressure holding time, and q is the fluid infusion amount. And (4) after standing for a period of time, repeating the step 1, and measuring a wellhead pressure building curve after second fluid infusion.
In the production process, the production efficiency of an underground electric pump unit is influenced by the problems of emulsification, abrasion of pump blades, overhigh gas-oil ratio, stratum liquid supply capacity and the like. The abnormal operation state of the electric pump can be generally classified into three types. The first type is a pipe string loss condition, which is characterized by a wellhead pressure that begins to decrease over time after reaching a maximum pressure and that stabilizes below a theoretical wellhead pressure. The second type is a high gas-oil ratio state or the efficiency of the underground oil-gas separator is low, which shows that the pressure climbing speed is slow, and the time required for the pressure building to reach the stable pressure is long. The third type is that the unit efficiency is low due to emulsification, vane abrasion, pump shaft breakage and the like. The first two factors are obviously characterized in the form of the pressure holding curve and are easy to judge. And the third kind of situation is difficult to distinguish under the condition of a single pressure holding curve, and the double pressure holding curves can be used for quantitatively representing the efficiency of the electric pump well unit.
And step 3) according to the previous research results, the pressure holding process before water replenishing can be roughly divided into three stages.
1. A gas compression stage. After the pressure is suppressed, more free gas exists in the oil pipe. Because the gas compression coefficient is far larger than the liquid compression coefficient, the initial pressure holding period is mainly compressed gas.
2. A liquid compression stage. After the pressure rises to a certain degree, the gas volume is small, at this time, the curve reflects the liquid compression property, and the pressure and the time are in a linear relation.
3. And (5) a synchronization recovery phase. When the pressure continues to rise, the lift of the electric pump reaches the maximum, the pump is not used for feeding liquid in the stage, the wellhead pressure and the bottom hole flowing pressure are synchronously recovered, and the pressure and the time are in logarithmic relation similarly to the shut-in pressure recovery stage.
And establishing a piecewise function model of pressure and time by segmenting the curve, and obtaining the following formula (1):
wherein P0 is the initial oil pressure, MPa; cl is the liquid compressibility; vp is the amount of liquid pumped in, m3(ii) a Vg is the gas volume at time t, m3(ii) a Vt is the fluid volume of the oil pipe, m3(ii) a q is the formation production, m3U is viscosity, mPa.s; and B is the volume coefficient of the fluid. K is permeability 10-3um2. P1 is the pressure at the end of the first stage and P2 is the pressure at the end of the second stage.
After annular fluid infusion is performed on the well. According to the dynamic law of production, the initial production of liquid after liquid supplement is high in water content. In the pressure holding test, the pressure holding time is not longer, usually within 5 minutes, because the axial thrust applied to the impeller at the highest-lift zero-displacement point is too large.
Like this can be with the well condition after the moisturizing is similar than the pure water phase of output, the model of suppressing pressure after the moisturizing becomes:
wherein P0 is the initial oil pressure, Cl is the liquid compression coefficient, Vp is the liquid pumping amount, Vg is the gas volume at time t, Vt is the oil pipe liquid volume, and P1 is the pressure at the end of the first stage.
And 4) drawing a pressure-building derivative curve and determining a stage switching point. Because the actual pressure holding curve is difficult to distinguish three stages in the pressure holding process, the error is larger when the synchronous recovery point is selected. And aiming at the condition, carrying out derivation operation on the pressure building curve, and constructing the pressure building derivative curve through discrete points. Because the second stage before fluid infusion corresponds to the first stage after fluid infusion, the slope difference between the two stages is not large. Then, a straight line with the value of the slope of the initial straight line segment after the fluid infusion is made in the pressure-building pressure derivative diagram, and the intersection point corresponds to two moments of the abscissa t1 and t2, namely two-stage conversion points (a liquid compression point and a pressure synchronous recovery point).
And 5) determining the time and pressure corresponding to the phase conversion point, particularly the pressure synchronous recovery point, so that the efficiency of the underground electric pump can be calculated. The characteristic curves of the head and the discharge capacity of the electric submersible pump before and after fluid infusion are made by clear water media, and can be regressed into the following relation:
H＝c-aq2-bq(3)
before annulus fluid infusion, when pressure reaches a synchronous recovery point in a pressure building process, namely when a mixed liquid compression stage is shifted to a logarithmic relation stage, the liquid flow pumped by the electric pump is 0, and the lift of the electric pump reaches the maximum. According to the pressure balance, the following conditions are satisfied:
wherein: p is wellhead oil pressure in MPa; l is the height of the liquid level of the oil pipe, m; eta 1 is the pump efficiency under the well condition, Hmax is the maximum lift of the characteristic curve, m; rm is the oil pipe liquid gravity N/m3；
Is the average weight N/m of the mixture in the pump3(ii) a Pin is the pump inlet pressure, MPa.
rm can be obtained from the following formula:
in the formula: rs is the gas-oil ratio (the interior of an oil pipe needs to be corrected according to the dissolved gas-oil ratio), fw is the water content, Pa is the atmospheric pressure, and ro is the specific gravity of the oil.
After the annular fluid infusion, the pump inlet pressure can be deduced according to the formulas (3) and (4) that the pump suction inlet pressure is as follows:
Pinw＝P0+Lrw-η2rw(c-aq2-bq) (6)
in the formula: p0 is oil pressure before pressure is held. q is the liquid production amount before pressure building, L is the liquid level height of an oil pipe, rw is the specific gravity of water, eta 2 is the efficiency of the electric pump unit, and the equations (4) and (6) are combined to obtain: efficiency of the electric pump under pressure build-up of fresh water:
the viscous lift coefficient a is eta 1/eta 2, the viscosity of the reaction fluid has influence on the pumping efficiency, eta 1 reflects the pumping efficiency under the well condition, and eta 2 reflects the loss of the electric pump (impeller abrasion, pump breakage and the like). The underground working state of the directional diagnosis electric pump well is obtained through the three parameters, and an effective basis is provided for the formulation of the implementation of next measures.
Example 2: q oil field H well suppressed pressure explanation experiment.
The Q oil field belongs to a heavy oil reservoir, the viscosity of the fluid is between 200 and 300cp, the artificial lifting mode is submersible electric, and the discharge capacity of the pump electric pump unit is more than 400 square every day. And part of the new wells are usually in the emulsification zone (30% -60% water content). The dynamic analysis shows that the current discharge capacity of the H downhole unit is 75m3D, production fluid 30m3D, oil production 15m3And d, 60 percent of water. Flow pressure 4.93MPa, gas-oil ratio 12m3/m3. And the current change is small in the production process, and the production capacity of the well is judged to be not completely released according to the production conditions of the peripheral wells. No cause was found.
And (2) according to the requirements of the step 1), carrying out pressure building operation on the well by an on-site operator, building pressure before annular fluid supplement, and increasing the pressure from 2.6MPa to 6.0 MPa.
According to the requirement of the step 2), the annular space fluid supplement discharge capacity of the well is 10m3And h, after the liquid is supplemented for 4 hours, carrying out pressure-holding pressure test on the well again, wherein the pressure is held from 3.0MPa to 8.5MPa, and the liquid amount rises quickly due to the large water supplement amount after the liquid is supplemented. The well fluid volume was then observed to drop to around 30 by near-day metering.
According to the requirement of the step 3), the pressure building curve before liquid supplement is observed, the pressure rising speed is high, the abrasion of pump blades is eliminated, the exponential period is short, and the influences of the gasoline ratio and the efficiency of a separator are eliminated. After the curve reaches a high value, there is no obvious drop condition, indicating no obvious loss condition. The primary judgment is the reason of low pump efficiency, but cannot eliminate the influence of crude oil emulsification or unit abrasion.
Observing the pressure-holding curve after fluid infusion according to the requirement of the step 4), finding that the curve is consistent with the theoretical curve characteristic, and explaining the curve by using a double pressure-holding curve method.
And 5) constructing a pressure-holding derivative curve of the two curves according to the requirements of the step 5), and searching a synchronous recovery point of the pressure-holding derivative curve before water supplement according to the form of the curve.
And calculating the dynamic lift H1 and H2 at the synchronous recovery point before and after the well fluid infusion according to the requirements of the step 6). Calculated η 1 ═ 0.73 and η 2 ═ 0.96. According to the condition that eta 2 is more than 90 percent, the viscous lift coefficient a is eta 1/eta 2 is 0.76, the efficiency of the electric pump unit is judged to be in a normal range, the value a is too small, the reaction well is greatly influenced by the viscosity of liquid, and the emulsification phenomenon of the well liquid is judged to exist. This is also evidenced by the decrease in fluid production after fluid supplementation.
The research results guide the Q oil field H well, the well lifting and pump detecting operation cost is saved, a good effect is achieved, and the operation cost is saved.
The invention has been described in an illustrative manner, and it is to be understood that any simple variations, modifications or other equivalent changes which can be made by one skilled in the art without departing from the spirit of the invention fall within the scope of the invention.
Claims (2)
1. A method for diagnosing the abnormality of an electric submersible pump well based on a double-suppressed pressure curve is characterized by comprising the following steps of:
firstly, closing a well mouth, not closing an underground electric pump unit, recording a pressure value of the well mouth, ending the test 2-3 minutes after the pressure value of the well mouth reaches the maximum value, replying the production of the well mouth, and measuring a first well mouth pressure building curve without fluid infusion;
stopping the well, performing fluid infusion operation on the well, standing for a period of time, repeating the step one, and measuring a wellhead pressure building curve after a second fluid infusion;
step three, establishing a pressure building model aiming at the abnormal operation state of the electric pump caused by low unit efficiency due to emulsification, blade abrasion or pump shaft fracture:
the pressure building process before water supplement is divided into three stages:
1) a gas compression stage: after the pressure is suppressed, more free gas exists in the oil pipe, and the compressed gas is mainly used in the initial pressure-suppressed stage because the gas compression coefficient is far greater than the liquid compression coefficient;
2) a liquid compression stage: after the pressure rises to a certain degree, the volume of the gas is small, at the moment, the curve reflects the compression property of the liquid, and the pressure and the time are in a linear relation;
3) and (3) a synchronization recovery phase: when the pressure continues to rise, the lift of the electric pump reaches the maximum, no liquid is injected in the stage, the pressure of the wellhead and the flowing pressure of the bottom of the well are synchronously recovered, and the pressure and the time are in a logarithmic relation similar to the well shut-in pressure recovery stage;
and (3) establishing a piecewise function model of pressure and time by segmenting the curve, and obtaining the following formula (1):
wherein P is0Initial oil pressure, MPa; c1Is the liquid compressibility; vpFor pumping the liquid, m3；VgVolume of gas at time t, m3；VtIs the liquid volume of the oil pipe, m3(ii) a q is the formation production, m3S, u is viscosity, mPas; b is the fluid volume coefficient, K is the permeability 10-3um2，P1Pressure at the end of the first stage, P2Pressure at the end of the second stage;
after annular fluid infusion is carried out on a well, according to a dynamic production rule, fluid is produced with high water content in the initial stage after fluid infusion, the well condition after water infusion is approximately compared with a pure water production stage, and a pressure building model after fluid infusion is changed into:
wherein P is0Is an initial oil pressure, ClIs the liquid compressibility factor, VpFor pumping the liquid, VgGas volume at time t, VtIs the tubing liquid volume, P1Is the pressure at the end of the first stage;
drawing a pressure building derivative curve, determining phase conversion points, carrying out derivation operation on the pressure building curve, constructing the pressure building derivative curve through discrete points, making a straight line with the value of the slope of the initial straight line segment after liquid supplement in a pressure building pressure derivative diagram because the second phase before liquid supplement corresponds to the first phase after liquid supplement and the slope difference between the two phases is small, and making an intersection point corresponding to the abscissa t1And t2Two moments are taken as two stage conversion points, namely a liquid compression point and a pressure synchronous recovery point;
determining time and pressure corresponding to the stage conversion point, and calculating the efficiency of the underground electric pump; the characteristic curves of the head and the discharge capacity of the electric submersible pump before and after fluid infusion are made by clear water media, and can be regressed into the following relation:
H＝c-aq2-bq (3)
before the annular space fluid infusion, when suppressing the pressure in-process pressure and reaching the synchronous recovery point, when the mixed liquid compression stage changes over to the logarithmic relation section promptly, the charge pump goes into liquid flow and is 0, and the charge pump lift reaches the biggest this moment, satisfies according to pressure balance:
wherein: p is wellhead oil pressure in MPa; l is the height of the liquid level of the oil pipe, m; eta1Is the pump efficiency under the well condition, Hmax is the maximum lift of the characteristic curve, m; r ismIs the oil pipe liquid gravity N/m3；
Is the average weight N/m of the mixture in the pump3(ii) a Pin is the pump inlet pressure, MPa,
rmthis can be obtained by the following equation:
in the formula: rsThe gas-oil ratio in the oil pipe needs to be corrected according to the dissolved gas-oil ratio for the gas-oil ratio, fwIs the water content, Pa is the atmospheric pressure, roThe weight ratio of the oil is shown as follows,
after the annular fluid infusion, the pressure of the pump inlet can be deduced according to the formulas (3) and (4) that the pressure of the pump suction inlet is as follows:
Pinw＝P0+Lrw-η2rw(c-aq2-bq) (6)
in the formula: p0Is the initial oil pressure, q is the formation production, L is the tubing level, rwIs the specific gravity of water, eta2For the efficiency of an electric pump unit, the simultaneous (4) and (6) formulas are as follows: efficiency of electric pump under pressure build-up with clear water:
the viscous lift coefficient eta 1/eta 2 reflects the influence of the fluid viscosity on the pumping efficiency, eta1Response to pumping efficiency under well conditions, and2the loss of the electric pump is reflected, the underground working state of the electric pump well is directionally diagnosed by solving the three parameters, and an effective basis is provided for the formulation of the next step of measure implementation.
2. The method for diagnosing the abnormality of the electric submersible pump well based on the double-suppressed pressure curve is characterized by comprising the following steps of: in the second step, the required shortest fluid infusion time is described by the following formula:
t＝πr2(hseq-hbot)/qsupplement device+tmax
Wherein r is the diameter of the sleeve, hseqFor unit separator depth of inclination, hbotDeep slant depth, t, in the reservoirmaxTo predict the holding-up time, qSupplement deviceThe amount of fluid infusion is used.
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| WO2020206403A1 (en) * | 2019-04-05 | 2020-10-08 | Schneider Electric Systems Usa, Inc. | Autonomous failure prediction and pump control for well optimization |
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