Academic literature on the topic 'Sucker rod pump unit'

As it is known, currently, the fields at the last stage of development are operated predominantly with sucker-rod pumps. Their operation is usually carried out in quite complicated technological and hydrodynamic conditions dramatically affecting the operation efficiency. Based on the actual field data, the paper studies the possible impact of the depth of sucker-rod pump running on the delivery rate, which is one of the indexes of operation of the whole sucker-rod pump unit. The values of delivery rates by oil and water have been calculated and their functional dependencies on the depth of sucker-rod pumps running developed as well. The results justified the increase of delivery rate by oil and its decrease by water in reviewed value diapasons. Mathematical models of developed dependencies have been obtained as well. As a result of conducted studies, the practicability of the increase of pump setting depth in operation conditions of reviewed field is justified.

Rational and efficient use of the sucker rod vibration energy is one of the effective ways of pumping unit energy saving. The vibration mechanics as the basis for establishing three-dimensional coupled vibration mathematical model of sucker rod-tubing-liquid column, and using difference solution to reproduce vibration process within one stroke of the sucker rod string, on this basis, analyzing the variable stiffness sucker rod string to the impact of the polished rod load and the pump stroke, and gaining reasonable parameters of the sucker rod string vibration energy, and combining with the working conditions of the sucker rod string to establish the match conditions of the sucker rod string liquid column incentive and polished rod incentive, and proposing the condition of pump to generate over-stroke to provide the theoretical basis for rational use of the sucker rod string vibration energy.

In order to complete the numerical simulation on internal flow and operating characteristics of down hole multiphase pump compress unit, establishing perfect finite element model, the three-dimensional turbulent current fields inside the impellers of compression unit for down hole multiphase pumps were simulated by using ANSYS. The calculation of multiphase flow is based on the standard k-ε turbulent current model. Reference information for the improvement of the pump can be obtained by the analysis of the flow of gas-oil in the channel of pump. Based on the finite method, we analyzed several situations in a pumping period. The velocity and liquid pressure distributing of sucker rod pump is studied in this paper, which may offer some evidences for the engineering design of sucker rod pump.

Despite of the increased share of oil wells equipped with submersible electrical centrifugal pumps, a considerable part of them is equipped and operated with sucker-rod pumping units. When operating wells with sucker-rod pumping units, different plunger pumps are used. The rod string is operated in severe environment due to long contact with highly corrosive well products and time-variant loads. Taking into account all acting loads, the diagnostics of the condition of sucker-rod pumping units is a difficult task. At the majority of oil fields in Russia, the operation of wells equipped with sucker-rod pumping units is controlled by portable and stationary dynamographs of various models. Moreover, dynamographs are used, as a rule, only to obtain images of dependence of the force on the polished piston rod upon its stroke. Based on dynamograms it is possible to find the well flow rate, pump capacity, force on the polished piston rod, etc. But one of the main problems to be solved with the help of dynamometry is the forecasting of down-hole equipment condition in the process of further operation. In this paper we overview the methods to diagnose the condition of sucker-rod pumping units based on dynamograms. The aim of the work is to develop the mathematical model to forecast the failures of down-hole pumping equipment on the results of dynamometry to automatize the control process of the unit operation. The research tasks are to analyze the existing methods for diagnosing the condition of sucker-rod pumping units, and to develop the mathematical model for forecasting the failure of the valve unit leakage. As a result, the method for forecasting the increased failure on the example of the fluid leakage in the pump injection unit is proposed. The permissible boundaries of the change in the relative force on the polished piston rod are drawn up. As a result, the failure increase is forecasted based on the frequency of the relative force on the polished piston rod getting within the interval obtained.

One of the factors decreasing the operation efficiency of wellhead pump unit is the fluid loss from the starting space between the pump, barrel coupling and the plunger. Due to the the pressure of liquid column rising within the barrel, as well as the friction wear over time, the space between the barrel-plunger pair increases, significantly amplifiying the fluid loss. The pressure within liquid columns on the inner and outer barrel surfaces should be aligned to prevent their widening due to the pressure. The space increases due to the hydrostatic pressure in the pumps in the upper parts of the barrel coupling, thus the fluid leakeage increases as well. In case, when the barrel coupling is in the lower part of cylinder, due to the pressure in the liquid column from within and outside, the space does not increase and as a result the well production rate rises for up to 3 %.

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 200825, “Failure Prediction for SRP Using Analytic Solutions,” by Viorica Sirghii, SPE, Rudolf Konrad Fruhwirth, and Herbert Hofstaetter, University of Leoben, et al. The paper has not been peer reviewed. A method for prediction of sucker-rod-pump (SRP) failure based on improved, completely connected perceptron (ICCP) artificial neural networks (ANNs) is presented. Results are compared with historical wellbore data. The validity of the ANN model is proved to meet SRP failure prediction with a ±5% error, helping identify and prevent potential damage, reduce costs and risks, and optimize production. SRP Diagnosis To evaluate the performance of SRPs, dynamometer cards are used. The load on the top rod is measured and plotted in relation to the polished rod position as the pumping unit moves through each stroke cycle. The result is a surface card that illustrates the polished rod load vs. position (downhole diagnostics). To determine above-pump liquid accumulation, pump-filling efficiency, and displacement, the well’s producing and lifting efficiencies can be analyzed and quantified. Depending on the results, operational and equipment changes can be made to improve efficiency and production optimization. How the plunger picks up, holds, and releases the fluid load at each stroke can be seen in a dynamometer card’s shape. The most-common and most-harmful pump states are fluid pound, gas interference, and tagging. When the pump is not completely full, the rod string is damaged because of an excessive number of strokes.

The most widespread mechanized way of oil production is use of sucker rod deep pumping units. This mode of well operation is characterized by moderate costs of the equipment and its service, increase in production when developing difficult-to-recover oil reserves, increase in production of layer which is reached by decrease in critical bottom hole pressure. Installation of the sucker rod deep pump comprises the land and borehole equipment. The drive, the well head setup and control system belongs to the land equipment. For today the pump unit is used as a wire. The unit itself represents the four-link crank-and-rod mechanism converting crank rotational motion into reciprocal motion of polished rod carrier bar. The work considers the prospects of creation and implementation of the drives nonconventional designs replacing classical pumping units, namely hydraulic actuators of sucker rod deep pumps on Ukrainian oil fields. Furthermore, the possible fields of their use has been defined. The hydraulic pressure drives existing designs presented by the leading global manufactures have been analyzed via critical-comparative method. Moreover, their design features in comparison with pumping units and chain occasions have been covered, the main advantages and shortcomings have been revealed. The usage possibilities of remote and automatic control of the hydraulic pressure drive working mode have been specified. The drive allows to carry out monitoring and remote control of technological process in real time with the minimum participation of service staff. The work presents the results of the hydraulic pressure drive PSHN-80-2.5 with pneumatic equilibration pilot test on well 64-Dolyna of scientific testing ground of the Ivano-Frankivsk National Technical University of Oil and Gas which have confirmed the work capacity of all drive systems and also convenience of carrying out the installation operations.

The efficiency of sucker rod pump installations, which have become widespread in mechanized lift practice, is largely determined by the balance of the drive. During the operation of sucker rod installations, the balance of loads acting on the rod string and the drive can change significantly due to changes in the dynamic fluid level, which leads to a decrease in balance and an increase in loads on the pumping equipment units. The increase and decrease in the dynamic level in accordance with the pumping and accumulation cycle occurs in wells operating in the periodic pumping mode. It is shown that during the operation of equipment in a periodic mode, fluctuations in the dynamic level and, accordingly, in the loads acting on the nodes occur. This leads to the need for dynamic adjustment of the balancing weights to ensure the balance of the pumping unit. A system for automatic balancing of the rod drive has been developed, including a balancing counterweight, an electric motor that moves the load along the balance beam, a propeller and a computing unit. To study the effectiveness of the proposed device, a complex mathematical model of the joint operation of the reservoir - well - sucker rod pump - rod string – pumping unit has been developed. It is shown that due to the dynamic adjustment of the balance counterweight position, the automatic balancing system makes it possible to significantly reduce the amplitude value of the torque on the crank shaft (in comparison with the traditional rod installation) and provide a more uniform load of the electric motor. Equalization of torque and motor load reduces the power consumption of the unit.

The purpose of this paper is to analyze the power efficiency of oil well systems with sucker rod pumping units. For this study a chain-drive of HRC 80-6-02 type and a similar performance drive HRC 80-6-02 balancer pumping unit were selected. Based on the analysis of the data, a conclusion was made that the power consumption for production of oil using ESP units is much higher due to a low coefficient of performance (COP) and significant losses in the submerged electric-driven pump. The analysis showed that for a half cycle of operation, i.e. per one stroke, the power consumption by a jack-pump was 15-20% higher than that of the chain drive. It is concluded that the chain drive is superior in many aspects of sucker-rod pumping units operation and may be the most effective replacement for ESP units, as well as for units with walking-beam jack pumps.

To increase the efficiency of the use of a sucker rod pumping unit (SRPU) today the columns of sucker rods of fiberglass and carbon fiber are used. Such polymer composites have a number of advantages over steel, but they have a significant drawback in the design of a sucker rod - a high concentration of stresses at the point where theyare connected to a steel head containing a thread. Many constructive solutions to this problem have been developed, but maintaining the connection of a fiberglass or carbon-plastic barrel with a metal head remains quite a challenge. As practice shows, the bending of the pump rods in the well are also subjected to bending loads, torque, friction to the column of tubing (tubing) and the like. Therefore, a comparative analysis of the parts of the pump rod structures: traditional steel and combined (metal tip with composite rod) should be carried out. In this work, such joints were subjected only to bending loads, which are particularly dangerous when passing through a rod of bent sections of a well and when running down the bar. It is established that at the time of bending the maximum normal stresses are distributed along the length of the pump rod unevenly and are concentrated in the transition between the head and the rod. The maximum normal stresses occurring in the transition between the steel tip and the carbon-plastic core, which are jointed without structural features (galtels, different transitions, etc.), have been determined to be greater than 1600 MPa. Such value of stress is undesirable when cycling the connection in well. For example, the design of a metal head was proposed, which allows reducing the stresses arising from bending and distribute them on the connection more evenly, compared to the traditional sucker rod.

There are some alternatives of artificial lift methods to increase the production of oil well or to keep it producing. Sucker rod pumping (SRP) and electrical submersible pumping (ESP) systems are selected for the design and economical evaluation of thirteen oil wells of R field. Although selected wells are already producing artificially, they are redesigned for SRP and ESP. LoadCalC software developed by Lufkin and SubPUMP developed by DSSC are used for SRP and ESP designs respectively. For economic evaluation, the rate of return (ROR) of each design is calculated for ten year period. In technical comparison, advantage of higher production ability with lower power consumption was observed in ESP applications. In wells which have lower production than 100 bpd, SRP takes the advantage as it has the ability of low volume lifting. In economical comparison it was observed that using both methods together was given better result. By increasing the number of wells that were applied ESP, 3.61% of increment in ROR was obtained relative to the present status.

Дисертація присвячена підвищенню ефективності експлуатації обладнання для видобування нафти, зокрема установок свердловинних штангових насосів шляхом застосування нафтогазових ежекторів. Використання тандемних установок при видобуванні нафти у складі електровідцентрового і струминного насосів показало їх високу ефективність при експлуатації свердловин як у звичайних умовах, так і у випадках різноманітних ускладнюючих факторів. Для реалізації пропозиції використання нафтогазових ежекторів, встановлених вище динамічного рівня свердловин, які експлуатуються штанговими насосами, визначено параметри нафтових свердловин, які для ежекторів є параметрами їх робочих та інжектований потоків, а саме, тиск, температуру, густину газоводонафтової суміші, її витратний газовмісту, густину вільного нафтового газу, середньоінтегральну швидкість руху вказаної суміші вздовж осі свердловини, об’єм газу, що надходить у затрубний простір та його густину. При допущенні гомогенності робочого та змішаного потоків в ежекторі отримані рівняння високо- та низьконапірного нафтогазових ежекторів. Розроблена методика їх використання для практичних обчислень. Виконана перевірка цих рівнянь при їх застосуванні до водоповітряних ежекторів. Здійснені лабораторні експериментальні дослідження на ежекторах вода - повітря і вода - вуглекислий газ, підтвердили можливість їх роботи з «підпором», тобто за наявності різниці тисків між інжектований газом перед входом у ежектор і його приймальною камерою. Величина «підпору» в експериментах досягала 0,05 МПа. Цей результат є важливим при використанні ежекторів у нафтових свердловинах. Розроблена методика визначення місця розташування ежекторів у нафтових свердловинах та їх геометричних параметрів. При її розробленні врахована необхідність проходження через ежектор всього нафтового газу, який надходить у затрубний простір свердловини, і забезпечення максимального зниження навантаження на колону штанг. Дана методика реалізована для свердловини 753-Д НГВУ «Долинанафтогаз».
В первом разделе выполнено исследование областей использования эжекционных технологий в нефтегазодобывающей отрасли, в частности на этапах разработки, эксплуатации, сбора и интенсификации добычи нефти и газа. Использование при добычи нефти тандемных установок в составе электроцентробежного и струйного насосов в нормальных условиях эксплуатации обеспечивает стабилизацию роботы электроцентробежных насосов, полезное использование энергии нефтяного газа и даже некоторое увеличение дебита скважин, а в усложненных условиях обеспечивает едино возможный способ эксплуатации скважин. Исходя из выполненного исследования и учитывая все положительные свойства струйных аппаратов, предложено размещение эжекторов выше динамического уровня скважин, которые эксплуатируются штанговыми насосами. Для реализации этого предложения сформулированы основные задачи, которые необходимо решить в ходе выполнения диссертационной работы. Во втором разделе выполнен теоретический расчет всех параметров нефтяных скважин вдоль их стволов, которые для эжекторов являются параметрами их рабочих потоков, а именно давления, температуры, скорости движения газожидкостного потока, его плотности, объемного расходного газосодержания и плотности свободного нефтяного газа. При определении распределения давления и температуры вдоль оси скважины при использовании методов Поэтгмана-Карпентера и Баксендела дифференциальные уравнения этих методов решались при использовании числового метода Адамса-Крылова. Это обеспечило получение уточненных значений этих параметров. Кроме того, рассматривая рабочий и смешанный потоки в нефтегазовом эжекторе как гомогенные среды, получены уравнения для высоконапорного и низконапорного эжекторов. Разработана методика их использования для практических расчетов. Выполнена проверка этих уравнений при их использовании для водовоздушных эжекторов. В третьем разделе рассмотрены вопросы, связанные с лабораторными экспериментальными исследованиями эжекторов, в которых рабочим потоком была вода, а инжектируемым - вначале воздух, а потом - углекислый газ. Указано на задачи экспериментальных исследований, дается описание лабораторных установок, программа и методика исследований, анализ полученных результатов и исследуется связь между результатами экспериментов и уравнениями нефтегазовых эжекторов. Главной задачей экспериментальных исследований было выяснение возможности работы эжекторов с «подпором», т. е. при наличии разницы давлений между инжектируемым газом перед эжектором и давлением в его приемной камере. Эксперименты подтвердили возможность работы эжекторов с «подпором» до 0,05 МПа. В четвертом разделе выполнено исследование возможности реализации предложенной эжекционной технологии на примере нефтяной скважины 753-Д НГДУ «Долинанефтегаз». Была разработана методика определения наиболее рационального места размещения эжектора в скважине и его геометрических размеров. В основу этой методики положены такие два условия: через эжектор должен проходить весь объем газа, который поступает в затрубное пространство скважины, и его место размещения в скважине должно быть такое, чтобы обеспечить наибольшее снижение нагрузки на колону штанг. Использование указанной методики позволило для скважины 753-Д установить место расположения эжектора в скважине и его геометрические размеры.
The thesis is devoted to improving operation efficiency of the oil extraction equipment, including sucker rod pump units, by using oil-gas jets. Using of the tandem setup that consists of electric submersible pump and jet pump during the process of oil extraction showed their high efficiency while operating wells both in normal conditions and in cases of various adversities. In order to implement oil-gas jets, placed above the flowing level in oil wells that are operated by sucker rod pumps, oil well parameters were calculated. These parameters will be the characteristics of the work and injected flows inside of a jet. Among them there are : pressure, temperature, density of the gas-water-oil mixture and its consumption gas content, density of the free associated gas, average integral velocity of this mixture along the borehole axis, the volume of gas that is inflowing to the annular space and its density. When determining pressure and temperature distribution along the borehole axis using Poettman-Carpenter and Baksendel methods we solved differential equations that are included in these methods with the help of Adams-Krylov numerical method. This ensured obtaining amended values of these parameters. Assuming that work and mixed flows inside of a jet are homogeneous, equations of the high- and low-pressure oil-gas jets were obtained. We developed a technique of using these equations for practical calculations. The accuracy of the obtained equations was tested when applied to water-air jets. Laboratory experimental study was performed for water-air and water-carbon dioxide jets. It confirmed the possibility of such jet’s operation with a "back pressure", id est if there’s a pressure difference between the injected gas in front of the jet and its suction chamber. The magnitude of the "back pressure" during the experiments reached up to 0.05 MPa. This result is important when using jets in oil wells. A technique was created that allows to determine the efficient location of jets in oil wells and their geometries. When developing this technique it was necessary to take into account two conditions: the whole amount of petroleum gas, which enters the annular space of the well, must pass through the oil-gas jet, minimize the stem loading. This technique is implemented for the oil well D-753 OGPD "Dolynanaftogaz".

During the reservoir production life reservoir pressure will decline. Also after water breakthrough the fluid column weight will increase as hydrostatic pressure will increase because of increased water and oil mixture density. In this case, reservoir pressure may not be enough to lift up the fluid from bottom to the surface. These reasons decrease or even may cause to stop flowing of fluids from the well. Some techniques must be applied to prevent the production decline. Artificial lift techniques are applied to add energy to the produced fluids. It increases production rate by reducing down-hole pressure and so that by increasing the drawdown. Artificial lift techniques increase production either by pumping the produced fluid from the bottom to the surface or reduce bottom-hole pressure by reducing the fluid column weight as a result of decreased fluid mixture density. Artificial lift is used worldwide in approximately 85% of the wells, thus its impact in overall efficiency and profitability of production operations cannot be overemphasized. The most important problem is how to select optimum artificial lift techniques by taking into consideration the reservoir, well, environmental conditions. Selection of poor technique could cause decrease in efficiency and low profitability. As a result, it will lead to high operating expenses. Several techniques have been developed for selection of optimum artificial lift techniques. Expert Systems (ES) is the most suitable technique used in these selection techniques. Because the use and availability of required parameters is easy. Also in this selection method most of the artificial lift techniques are analyzed rather than other selection techniques. Expert Systems program mainly consist of three modules: (1) Expert Module, (2) Design Module, and (3) Economic Module. By entering required data to the system, program automatically suggests the feasible artificial lift techniques those might be used referring to given data. In this thesis work the artificial lift selection criteria and Expert Systems available in the literature have been studied. A Microsoft Windows based program has been developed to predict suitability of artificial lift methods for a given set of wells and produced fluid parameters. For the selected artificial lift method (i.e. sucker rod pump, ESP, gas lift, hydraulic pump, PCP) the program is able to perform basic calculations for the given data. Different case studies have been performed by running the program with actual data from fields. Well data of Venezuela, Azerbaijan and Iranian oil fields has been used in case studies. The results have been compared with previous studies those have been done on these fields with other selection techniques and current artificial lift techniques are being applied in selected wells. The obtained program results have been overlap with current real field application and previous studies.

Abstract SCADA optimization platform is implemented to monitor and evaluate well performance. For Sucker Rod Pump, SCADA Optimization Software can be used to monitor the unit balance and gearbox torque. In some ways, not all required well configuration data for SCADA Optimization Software to do a calculation of counterbalance torque (CBT) for pumping unit balance and gearbox torque evaluation are available. Standard field Counterbalance Effect (CBE) measurement might be performed to calculate the CBT value. However, this standard procedure is limited to well that run on balance condition. For well with unbalance condition, the measured CBE needs to be adjusted by a correction factor which the equation will be presented in this paper. The corrected CBE value from the new equation is then inputted to the SCADA Optimization software to perform day-to-day real-time monitoring of pumping unit balance and gearbox torque. Derivation of the CBE correction factor equation is presented. Validation upon this new equation is performed by comparing the result with electrical measurement on the pumping unit motor. Using the calculated CBT from the new equation, SCADA Optimization Software performs gearbox torque and pumping unit balance analysis based on every collected dynamometer card. Calculated CBT from the new equation provided results in gearbox torque distribution pattern that match with measured electrical parameter distribution along the stroke. This CBT value assists SCADA optimization software to calculate pumping unit balance and gearbox torque. Alarm in the SCADA optimization software that coming from an anomaly on pumping unit balance and gearbox torque help operator to do preventive maintenance so that pumping unit component especially the gearbox could have longer run life.

Abstract Finding new oil and gas that can be developed economically is getting more difficult and challenging today. To meet the oil and gas demand, it is therefore important to focus on the existing and already developed assets by applying new and more efficient technology and optimizing the use of existing equipment to increase production performance of the asset thus better recovery. Sangasanga Field as mature oil field of Pertamina EP is producing its oil by the assistance of artificial lift. The artificial lifts applied in Sangasanga field are Sucker Rod Pump (SRP), Electrical Submersible Pump (ESP) and Hydraulic Pumping Unit (HPU) where SRP dominates with 84 units installed while ESP and HPU are 25 units and 15 units respectively. According to the data of well service work history from 2018 to 2020, the failure of SRP and HPU was quite high. The main problem observed were the occurrence of leaking tubing and broken sucker rods. The study gathered the occurrence of failure and a method so called "WEAR PREDICT 99" was created to estimate SRP's buckling point and lifetime. WEAR PREDICT 99 is a correlation derived from comparing neutral point calculated from formula with actual leak data of broken pipe or suction rod. The correlation then used for predicting the buckling point that represents the probable location of the leaking pipe or damaged suction rod. This correlation allows to predict when and where the sucker rod will leak or break, therefore preventive measures to increase the lifetime of the SRP and HPU wells can be taken.

Abstract Rod pump systems can be the most commonly used artificial lift technology for oil production. A rod pump system that brings underground oil to the earth’s surface consists of a prime mover, a surface pump, a sucker rod string, and a downhole pump. A pin at each end of the rod and a box coupling are threaded together to connect the sucker rod and form the rod string. The sucker rod string acts as the connecting link between the surface pumping unit and the subsurface rod pump. The loads generated from the reciprocating upstroke and downstroke motions could impose a risk of fatigue failure in the sucker rod connections with cyclic tensile stresses. The increasingly harsh field operational conditions that require deeper wells and higher production are pushing the connections to their limits. As a result, failures of the standard API (the American Petroleum Institute) sucker rod connections are becoming increasingly more frequent. The resulting rod string failures are expensive to repair because the whole string must be disassembled and removed so that the failed rod can be accessed, and the rod string must then be reassembled. Such high repair cost is unaffordable for the wells with low production rates. Therefore, there is a strong demand for having a threaded connection design with high fatigue strength that is suitable for sucker rod pumping applications. To enable a long service life and to reduce cost of service delivery caused by frequent repairs, an advanced rod pump threaded connection design with significantly improved fatigue resistance over the standard API design has been developed and experimentally qualified. Modeling and simulation techniques had been extensively used to drive the design and qualification process. The newly developed connection design is featured by an optimized thread form and stress relief groove, and an advanced manufacturing process. Nonlinear finite element analysis (FEA) was extensively utilized to predict the fatigue resistance of the threaded connection with makeup torque and service stroke loads, and to explore and optimize the designs of the threads and stress relief feature prior to physical prototyping and testing. The FEA models had favorably predicted the performance of the new design, which was later experimentally validated through full-scale axial and rotary bending fatigue tests, respectively. The work presented in the paper sets a successful example of model-driven design, which can significantly shorten the development time and cost. The newly developed high fatigue strength sucker rod connections have great potential for mitigating the risk of rod string failures during pumping operations and therefore improving operational reliability for both beam and progressing cavity pumping systems.

A novel approach is presented to model the interplay between the gas volume fraction (GVF) and the driving force of the pumping unit. A physics-based model is proposed to predict the down-hole pressure for a constant, but unknown GVF and given oil flow-rate out of the well. The identified down-hole pressure is used to model the saddle-bearings axial displacements, which are indicative of polished-rod loading. The imbalance between the data obtained from the detailed model of the pumping unit, and predicted bearing’s displacements can be employed then to estimate the value of the GVF. The resulted GVF is incorporated into the sucker-rod string dynamics to determine the natural frequency of the system. A control strategy is then used to adjust the pump speed to compensate for the GVF variations while avoiding the resonance frequency of the sucker-rod string. A low dimensional simulation is performed and the results are demonstrated for upstroke movement of the sucker-rod.

The dynamic performance of hydraulic beam pumping units was analyzed in this paper by using the theory of mechanical vibrations. The house-head movement of the pumping unit is mainly uniform, except the alternation period of upper- and down-strokes. Under the action of the house-head movement, the vibration of the system, the sucker-rod and, furthermore, the dynamic stress will be induced. The results indicate that the movement of the downhole pump includes two parts. One is the movement following the horse-head. The other is the dynamic response excited by the support movement. When the parameters of the system are selected reasonably, over-stroke of the pump will appear. This is because the movement of the hydraulic piston obeys a particular law. The maximum displacement increases, and the maximum dynamic stress decreases with depth. The changing of maximum dynamic stress with depth obeys quadratic law.

This paper outlines a concept for monitoring performance of artificial lift performance such as electrical submersible pump (ESP), hydraulic pumping unit (HPU), sucker rod pump (SRP) and progressive cavity pump (PCP), for a large number of wells. The objective is to generate simplified monitoring performance of artificial lift with a huge number of wells on one page by creating quadrant mapping consisting of two coordinates with x axis representing pump efficiency and y axis showing pump submergence. We made a four-quadrant limit by pump efficiency (50%) and submergence (200 m). Optimum wells will show on range pump efficiency above 50% and submergence below 200 m, and 3 other quadrants are classified as artificial lift problems, well potential and sizing/design problems. By using the quadrant mapping concept, we can generate performance of artificial lift for 1500++ wells in one page, and this mapping consists of four quadrants (quadrant 1, quadrant 2, quadrant 3 and quadrant 4), quadrant 1 showing wells which have artificial lift problem, quadrant 2 showing well which have potential to increased production , quadrant 3 showing the optimum wells operation and quadrant 4 showing the wells which required to re-sizing/re-design artificial lift, this mapping can be shown to Engineers, manager’s and shareholder to show overall performance and classification detailed problems to create a troubleshooting, optimization program to increased oil production, run life artificial and result in better production performance. This mapping also helps petroleum engineers to get a better field view and create priorities and program optimization based on the quadrant mapping result and classification.