Gas Lift Research Articles

Assesment of the risk of degazation of the Black Sea: type of limnological disaster on lake Nyos reconsidered

The possibility of a repetition of the limnological catastrophe in the Black Sea is considered. It is shown that, in contrast to the volcanic lakes of Africa Nyos and Manun, where limnological catastrophes occurred in the 1980s, the concentration of dissolved gases in deep waters is significantly less than the saturation value. This eliminates the mechanism of so called “eruption” of carbon dioxide such as gas lift. However, on a smaller scale, significant methane releases are possible during strong eruptions of underwater mud volcanoes. The mechanism for the release of carbon dioxide from the lake into the atmosphere is so similar to a volcanic eruption that mathematical models developed for ordinary volcanoes are used to describe it. In both cases, the rise of erupted masses occurs due to an increase in the buoyancy of the gas-liquid mixture, which carries with it particles of the environment. The formation and growth of gas bubbles at intermediate depths occurs provided that the total partial pressure of all gases inside the bubble exceeds the hydrostatic pressure at a given depth. The article shows that the concentration of dissolved methane in the Black Sea is much less than the saturation level. Due to the relatively low solubility of methane in water, methane bubbles are able to overcome a significant depth range. And as additional components of the gas mixture, together with methane, carbon dioxide and hydrogen sulfide can thus enter the atmosphere. It was concluded that as the water temperature in the Black Sea increases due to climate change, the reserves of methane gas hydrate at the bottom of the sea will begin to decompose, which will also be accompanied by jet gas release. At the same time, methane can escape to the surface from depths of no more than 900 m.

Optimal Control of the Initial Condition in the Problem of Gas Lifting

Optimal Control of the Initial Condition in the Problem of Gas Lifting

Technology Focus: Completions (April 2023)

_ A few years ago, exaggerating a figure of speech, I coined the expression, “We work in a water industry; oil is just a supporting actor.” In fact, producing water is the final destination of every oil field, but obviously the objective was to highlight the importance of water management in the hydrocarbon-production process. Since the beginning, well completion and stimulation strategies have always sought to optimize water management and, extending the concept, management of all fluids produced. Selective completions in vertical and multilateral wells (combined with sand control or not) and segmentation of horizontal wells are good examples of this effort. These technologies, combined with intelligent completion, have brought very positive results. Intelligent completion in open hole, currently used in the Brazilian presalt, has allowed the reduction of the carbon footprint, so necessary nowadays. The optimal application of intelligent completion is the subject of paper SPE 209965, an excellent compendium of best practices on the topic. In recent years, driven by technological advances, good results, and the need to increase operational efficiency, we have experienced a major increase in the use of devices for flow equalization and selective fluid production [e.g., inflow control devices, autonomous inflow control devices (AICDs), and autonomous inflow control valves]. A significant reduction in water and gas production has been reported in several technical papers. In fact, this is the most published completion topic in the past 3 years, and many good articles are available. Apart from new and exciting trends, conventional solutions continue to play their important role. Basic themes long discussed continue to evolve and bring new insights. This is the case with paper SPE 204185, which deals with perforating for fracturing. Finally, paper SPE 210417 discusses the use of AICD technology in the Singue Field in Ecuador, which resulted in an increase in cumulative oil rate and a decrease in cumulative water. Recommended additional reading SPE 210205 Successful Autonomous Inflow-Control Device Application To Reduce Water Production in a Heavy Oil Greenfield by Carlos A. Pedroso, Enauta, et al. SPE 206213 Automated Well Production and Gas Lift System Diagnostics and Optimization Using an Augmented Artificial Intelligence Approach in a Complex Offshore Field by Mahmoud Elwan, Dragon Oil, et al. OTC 31483 Case Study: How the Newest Generation of Autonomous Inflow Control Devices Helps To Control Excessive Well-Water Production Within a Major Sultanate of Oman Oilfield by Salim Buwauqi, Petroleum Development Oman, et al.

Transient modeling of plunger lift with check valve for gas well deliquification in horizontal well

ABSTRACT To improve the plunger gas lift efficiency, a modified plunger was developed by adding a check valve to the downhole positioner in the Changqing Gas Field. However, the transient flow behavior of the plunger lift with check valve is unclear owing to the lack of a reliable method. Therefore, in this study, a simplified transient mechanistic model based on the law of conservation of momentum and mass is proposed to simulate the comprehensive dynamic process of a plunger-lift system. The results of the proposed method exhibited a high coincidence with that of the accumulated gas and liquid production of gas Well-1 in one cycle, and the relative errors were 2.11% and 4.29%, respectively. The calculation results demonstrate that the plunger lift with check valve can effectively prevent the flow of liquid to the bottom of the well, reduce the bottom hole flow pressure, and increase the productivity of gas well during the shut-in period. The efficiency of the plunger lift with check valve was enhanced with an increase in the volume of the accumulated liquid unloaded from the bottom of gas wells. Additionally, for the plunger lift with check valve, the production peak value was higher and the instantaneous gas production peak value was lower in comparison with the conventional plunger. After the plunger reached the wellhead, the instantaneous fluid production of the conventional plunger was relatively unstable than that of the plunger lift with check valve. A certain distance should be maintained from the bottom of the well in the case of the positioner with check valve. If the positioner is placed at the bottom of the tubing, the difference between the lift efficiency of the plunger with check valve and conventional plunger is small, and lower than that of the conventional plunger. The installation position of the downhole positioner in a gas well should be below the accumulated liquids level and should maintain a certain distance between the positioner and bottom of the well (200 m). The results of this study enhance the understanding of the operation mechanism of the plunger lift with check valve, and unloading of the accumulated liquids from the bottom of gas wells.

Hybrid Gas-Lifting Method Optimizes High-GOR Production

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 209721, “Hybrid Artificial Lift-SRP/Gas Lift for Oil Production in High-GOR Environments,” by Kuldeep Chanchlani, SPE, Ranjit Gogoi, and Sukumar Awasthi, SPE, ONGC, et al. The paper has not been peer reviewed. _ The casing gas-pressure-operated rod-lift (CGPORL) system described in the complete paper consists of a sucker rod, pump, gas-lift valves, downhole gas anchor, and tubing string. The completion was invented to save workover rig cost, reduce production deferments, and increase production efficiency in high-gas/oil-ratio (GOR) environments in marginal fields. CGPORL System Description The hybrid-lift system includes gas-lift and rod-lift modes, allowing operators to switch between two modes of artificial lift without costly workovers (Fig. 1). The key factor is the ability to isolate or communicate between the tubing and the annulus without pulling the tubing string out of the hole. Gas lift requires that the annulus should isolate tubing in order to inject gas through valves installed inside pocket mandrels, whereas rod pumps need communication between the tubing and annulus for passage of liberated free gas. Mechanism The gas-lift valve opens once annulus pressure develops over the valve-closing pressure. Once free gas is released into the tubing and the injection valve is closed, the annulus becomes a closed system. The free gas released from the downhole gas anchor gradually pressurizes the annulus until the valve opens for the next cycle. This mechanism indicates an intermittent gas-lift process in a cycle. When the well ceases to flow because of rod-lift failure, the well When the well ceases to flow because of rod-lift failure, the well will continue to flow through the annulus by keeping open the annulus valve connected to the nonreturn valve. Because of the nondevelopment of annulus pressure in case of rod-lift the CGPORL system. failure, a mobile air compressor can be used for valve unloading until the rod pump can be serviced. As the solution gas is recombined with liquid above the pump-setting depth, the hydrostatic head is relatively decreased. If the gas-lift valve is placed at a shallower depth, the drilled well length contributing to the reduction of fluid density is short. If the pump is placed at a deeper depth, annulus pressure can be high, so the gas-lift valve can be placed in a low position. Optimization for the point-of-pump setting and gas-lift-valve setting depth is required. These effects are related directly to the frequency of injection and rate, which must be examined along with economic and safety factors.

Failure Analysis of Ф73.02 mm × 5.51 mm S13Cr 110 Tubing Collapse in an Oil Field

The field service conditions of a well’s collapse tubing were investigated, and the physical and chemical properties of metal materials (chemical composition analysis, mechanical property test, metallographic structure analysis of tubing materials), hydrogen sulfide stress corrosion cracking test of tubing materials, and scanning electron microscopy analysis of tubing cracks and fracture surfaces were tested in this paper. The results show that the major cause of tubing collapse is that the tubing material is super 13Cr (S13Cr). When it is used in the environment containing hydrogen sulfide, plenty of longitudinal stress corrosion cracks is generated on the inner wall, which greatly reduces the actual anti extrusion ability of the tubing. During the gas lift of the well in the later stage, the upper part of the oil pipe was blocked and the oil jacket was in series, and the gas lift pressure was transmitted into the oil jacket annulus, so that the pressure difference between the inner and outer parts of the oil pipe exceeded its actual anti extrusion capacity and collapse failure occurred.

Optimal Control of the Initial Condition in the Problem of Gas Lifting

A partially periodic control problem is considered, where the control parameter enters the initial condition. We study the formalization related to the calculus of variations. The necessary conditions are written out in the form of Euler–Lagrange equations, with the help of which an algorithm for finding the optimal program trajectories is developed. The results are illustrated by an example when the motion is described by a time-averaged hyperbolic equation at a sufficiently large well depth during a gas lift.

Technology Focus: Artificial Lift (March 2023)

Selecting artificial lift papers for the Tech Focus feature of JPT can be a daunting exercise when technologies and innovations abound, more so post-pandemic, with 157 submitted abstracts covering 2021–2022. In narrowing the offerings to three, the criteria of conformance to guidelines and novelty of information, technical equipment, and application were considered. Industry indicators and interest were also factors. Gas lift remains of high global interest, whether in long horizontal shale oil wells or vertical ones because of the cost to operate lower lifting. Declining production and high gas/oil ratios (GORs) present a challenge for conversion to secondary lift forms. Paper SPE 209721 provides an innovative solution combining gas lift with sucker rod lift to enhance and exploit low-productivity wells in high-GOR fields. Permanent magnet motors (PMMs) have made quite the technical splash in the industry over the past decade. PMMs are one-third shorter and result in higher power densities and power savings of up to 18% just by changing out the induction motor. PMMs are again grabbing attention for the direct 1:1 ratio of electrical to carbon footprint. Current environmental, social, and governance concerns are placing demands on all operators, and PMMs are positioned to help with carbon reduction as a low-hanging fruit in paper SPE 209736. In paper SPE 209763, we look at all-metal progressing cavity pumps (aka M2M), which consist of a metal rotor and metal stator. Incremental advances in geometry and materials continue to see operators use high-temperature fluids with low operational expenditure in mind. Reliability is always a concern, and now a novel condition indicator has been developed and tested that offers a better indicator than pump efficiency alone. Recommended additional reading at OnePetro: www.onepetro.org. SPE 206909 Successful Progressing Cavity Pump Reliability Improvement Project in an Oman Steamflood by Shauna Noonan, Oxy, et al. SPE 211782 Maximizing Marginal Fields Profitability Through Drilling Multilateral Wells To Reduce Well Count and Well Cost: Dual Lateral Well With Single ESP and Smart Lower Completion by Mahmoud Mohamed Abdelhay Mostafa, ADNOC, et al. SPE 209748 Gas Pump—A Gas-Driven Positive Displacement Pump Artificial Lift System by Stephen W. Turk, ELC Energy Services, et al.

Study of phase and physical property changes during gas lift injection of high CO2‐content associated gas in the offshore M oil field

AbstractThe gas lift in the offshore M field will be performed with high CO2‐content associated gas, but the change of wellbore temperature and pressure during the injection process will lead to the change of phase and physical parameters of associated gas, which has a great impact on the design of gas lift. To ensure the smooth implementation of gas lift in the offshore M field, this paper conducts a study on the physical parameters of associated gas considering the change of CO2 phase state. We obtained the density, viscosity, compression factor, constant pressure specific heat capacity, thermal conductivity, and Joule Thomson coefficient at each temperature and pressure by Hysys calculation, and regression analysis to obtain the regression model of the physical parameters; finally, the regression model was compared with the flash experiment and Hysys calculation results. The results show that the CO2 phase change has a large influence on the physical parameters; R2 > 0.8, which indicates that the regression model has sufficient reliability; the results of the comparison show that the empirical formulas of all physical properties have sufficient accuracy and superiority except Joule–Thomson coefficients. In addition, the empirical formula of the Joule–Thomson coefficient also has good accuracy and superiority at the pressure not exceeding 22 MPa. The study of phase changes and physical parameters of associated gas with high CO2 content provides a basis for subsequent gas lift design in the offshore M field and multiphase flow calculations in the wellbore during the gas lift. Although this study is only applicable to this sample, it also provides a feasible research method for other samples.

STUDY OF GAS-LIFT VALVE OPERATION

Gas lifts are versatile, dependable lifting systems that provide numerous options. This article discusses typical problems with gas lift valves used in geotechnical applications. What could result in such operational and well-related flaws. A closed system powered by high pressure gas is a gas lift system. Gas lifts are frequently adaptable, dependable lift systems with a variety of manufacturing options. For all operations, adding gas from an outside source lowers the fluid pressure level, which forces more fluid to be kept in conditions with high water retention. Excellent product quality, changeable gas lift complex, and lift depth. Where possible, involuntary injection gas tensions and volumes are extremely rare and can support various synthetic buoyancy types. By lowering the fluid's pressure stages with the use of an extraterrestrial gas penthouse, more fluid may be stored in the Force as the descent goes on. As you alter the parameters, consider how other elements alter. The behavior of gas lift valves is predicted using a variety of techniques. These techniques additionally consider additional factors. The Thornhill-Craver equation is the formula most frequently used to forecast the performance of throttle valves. The interpretation of gas lift taps is overestimated by the Thornhill-Craver equation, particularly for big ports, according to Gerberding and Acuna. Gas lifts are not appropriate for combined liquids, supersaturated Neptune, or thick, abrasive paintings. , which focuses on how to increase the performance of weak gas lift taps, highlighting the necessity of their complicated design, does not function well for grabbing old wells or extending inflow lines with external internal compasses. Keywords: Gas liquid Ratio (GLR), Fluid, Pressure, Gas Lift Valves (GLVs), Injection Gas, Bottom Hole Pressures (BHPs)., Continuous Flow, Intermittent Flow.

ESP Application for Oil Production in Naturally Fractured Granitic Basement Reservoir

In fields with increasing water cut and depleting reservoir energy, Electric Submersible Pump (ESP) installation is a sustainable production option. It helps to extend life of the wells by lower abandonment pressure and therefore increases the recovery factor. In addition, the gas lift saving from ESP conversion wells could be utilized to optimize others wells’ productivity thus boosting the total field production. Over the last 9 years, Cuu Long JOC has been conducted 5 ESP campaigns in fractured granitic basement reservoirs which bringing full of surprises. The selected field for ESP pilot was brought on production initially in 2008 with over 75,000 bopd. However, water breakthrough occurred after 8 months quickly reduced the total field production to 5,000 bopd in 2013. At the time of ESP conversion, gas lift have already optimized and it is not sufficient to maintain the rate as most of wells flowed with 95% water cut. With ESP application, the wells were able to reach 12,000 blpd and reduce the water cut not only for itself but also for adjacent wells. Despite the pump average run life is not meet the expectation, ESP application shows better efficiency in term of oil production compared to gas lift under the same reservoir conditions. This paper summarizes a process of ESP application in high temperature environment including candidate selection, ESP design and actual production performance. The learning and experience developed from 11 ESPs installation provide an insight about the potential of ESP use for oil production in fractured basement reservoir.

Analysis of crude oil production with gas lift methods

Some wells in the Niger Delta area are in their late production life. Water production increases with and reservoir pressure decreases to the point that the natural energy cannot sustain the production of hydrocarbon to the surface. The severity of this impact has been observed in the Niger Delta oil fields over the past years that has caused the abandonment of wells with a significant volume of hydrocarbon unrecovered. To increase production and extend the life of these wells, a gas lift project is considered. This study aimed to analyze oil production between continuous and intermittent gas lift systems based on real data obtained from two oil wells in a Niger Delta oilfield and to choose the system best suited to increase the production of the wells. To achieve this aim, a simulation study on continuous and intermittent gas lift methods was conducted using GAP and PROSPER software. The results obtained indicated that a continuous gas lift system will be suitable for a well that has a high flow rate and high GOR (well 1). For Well 2, the results indicated that an intermittent gas lift system will be suitable for a well that has lower reservoir pressure and low productivity.

Research of the technology for hydrate prevention in gas transportation system

The principal aim of natural and associated gas preparation to transportation is provision of normal transportation inside field niacin gas pipelines. Developed gas and gas condensate field, production of which consists of great amount of different aggressive admixtures and mineral salts, require efficient of natural gas for further transportation.
 The results of aforesaid system phase state test investigation are given in the article. Its presently at water phase and salt composition.
 A Principals physical and chemical factors of inhibitor composition under different proportion of components were determined under laboratory conditions. New inhibitor composition, was selected on the base of experimental investigation results there also was developed the technology of inhibitor application for gas field treatment.
 Since the efficiency of gas storage and transportation processes depends on the compliance of these processes with the requirements of the related equipment and relevant technologies, the operating modes of gas lift lines and compressor stations should be regularly examined. There is no doubt that the efficiency of storage and transportation of natural and associated gas is ensured at a distributed level, provided that the technological equipment is reliable, durable and operates in accordance with the requirements. One of the most important issues is to improve the used technology to prevent hydrate formation in the process of production, storage and transportation of gas condensate in complex conditions. On the basis of scientific a research and field surveys there were developed new scientific a technical measure to increase the efficiency of the installation for preparation of gas

Numerical computational fluid dynamics (CFD) simulation study based on plunger gas lift test

In order to explore the feasibility of the Computational Fluid Dynamics (CFD) method for plunger gas lift and the flow pattern in a long wellbore, a lab simulation test was conducted to verify the reliability of the CFD simulation results. Verification data were provided for CFD simulation through carrying out a plunger gas lift lab test for vertical wells, identifying the plunger movement patterns and delivery rates under different flow pressures, and determining the minimum plunger startup pressure or differential pressure and leakage, and an identical CFD physical model was created on the basis of the lab test model, CFD dynamic grid programming and CFD simulation were conducted under test conditions, and a comparison of the simulation and test results was made to identify the calculation accuracy and the rationality of the CFD model and method; finally, boundary conditions such as temperature and pressure were set according to the actual long wellbore (200 m) conditions, the CFD simulation was performed, and the impacts of the downhole conditions on the gas lift performance were analyzed, so as to develop CFD calculation methods to predict the bottom-hole flow pressure, plunger speed, and delivery rate. The results show: the average plunger speed range is 7.74–22.5 m/s when the flow pressure varies from 199.77 to 632.93 kPa, and the leakage rate increases in a nearly linear way with the speed; compared with the lab test results, the simulation results from the created dynamic grid model and multi-phase turbulent flow model have the leakage error of 7.2% and the plunger speed average error is smaller than 11.1%; under long-wellbore conditions, the plunger lift speed shows the change pattern of increasing and then decreasing, the wellbore pressure has a wave-like drop, and in addition to this pressure drop characteristic, the fact that the plunger startup pressure differential increases with the wellhead pressure should be considered (when the bottom-hole pressure is 15 MPa, the wellhead pressure must not exceed 10 MPa).

A comprehensive method for determining the dewaxing interval period in gas lift wells

The gas lift method is an artificial lift method of well production using the energy of compressed gas injected into the well to lift the reservoir fluid to the surface. The formation of paraffin deposits has remained one of the critical oil production problems due to the growing percentage of hard-to-recover reserves in the overall structure. This complication is also typical for many oil and gas fields in Vietnam, such as the White Tiger, White Bear, and Dragon fields. Wax deposit formation negatively affects the operation of individual production wells and the development of the field as a whole, which leads to a decrease in productivity and the need to take measures to remove paraffin deposits, subsequently increasing the downtime period of the well. In order to ensure stable production of highly paraffinic oil, it is necessary to take measures to dewax wells systematically. The frequency of wax removal operations depends on the intensity of the wax formation, which is determined by various technological, technical, and geological factors. The interval between dewaxing operations is called the dewaxing interval period (DIP). This value is an important technological parameter and characterizes the efficiency of a well’s operation. In this study, a comprehensive method has been developed to determine the dewaxing interval period (treatment interval) for gas-lift wells when the formation of wax deposits has occurred. The optimal dewaxing interval period is suggested to be determined by the change in the liquid well flow rate at the point when it falls by 20% from the initial value. In addition, a mathematical model of the time-dependent wax thickness, taking into account the heat and mass transfer laws and the laboratory results using the Cold Finger method, has also been developed. The proposed model for determining the dewaxing interval period was applied to an oil well in Vietnam. The DIP prediction model gave a similar value to the actual DIP field data (6.67 and 6 days, respectively). The obtained results showed that the model had proven its accuracy following the results of a comparison with the field's data of dewaxing operations.

Gas Lift Modeling: A Viable Option for Oil Production Optimization

Gas lift optimization is very challenging even in the mist of availability of gas assets as this involves modeling reservoirs accurately. Non availability of good software hinders best results such as obtaining critical gas lift design parameters like appropriate absolute open flow (AOF), skin factor, formation productivity index and the skin factor or even the reservoir pressure. The aim of this work is to design a model to gas lift an oil well in the Niger Delta for improved oil optimization. In other to achieve this aim the following objectives are considered; determine the maximum production rate achievable using gas lift, determine the optimum lift gas injection rate and depth and design the operating and unloading valves. Integrated Production Management (IPM) software was used with data from an oil well in the Niger Delta. Results show that the AOF gave 18026.3STB/day, formation PI gave 10.56STB/day/psi while the skin factor gave a positive value of 2. Pipe correlation used is Beggs and Brill. The maximum and minimum gases available are both 15mmscf/day. Water cut is 80%. The use of gas lift is very appropriate when the gas cap is a major source of reservoir energy

Application Research on Liner Tube without Variable Diameter of Shale Gas Plunger Gas Lift Wellhead

Given that there is variable diameter in the shale gas plunger gas lift wellhead, which causes that the plunger cannot run up and down the gas well wellhead, affects the effect of plunger drainage gas production, the paper carries out research on liner tube without variable diameter of the shale gas plunger gas lift wellhead and installation methods, makes the diameter of the gas well wellhead consistent with that of the oil pipe, ensure that the plunger can be open up and down the wellhead of the Christmas tree, facilitate the periodic inspection and replacement operation of the plunger, and reduces the cost of plunger salvage operations. The successful application of the process plan in the shale gas well ** has achieved good drainage gas production effect, truly solved the variable diameter problem of shale gas plunger gas lift wellhead, and achieved the goal of once and for all.

MOVEMENT OF TWO-PHASE GAS-LIQUID FLOW IN HORIZONTAL AND INCLINED PIPES

"Two-phase flows are found in almost all areas of technology. For example, tubular evaporators, boiling water reactors, boiler blowdown systems, heaters, boilers, gas lift pumps, oil and geothermal wells, oil and gas pipelines, refrigerators, process pipelines, and condensers. Two-phase flows are classified as mixtures. According to the composition of the mixture are divided: (a) for single-component (or one-component) - vapor-liquid flows; (b) multicomponent - gas-liquid flows. One-component mixtures consist of the same substance in different states of aggregation. This can be not only vapor-liquid, but also a mixture of liquid or vapor with a solid phase, a water-ice mixture, or a vapor flow with ice particles, for example, in sublimation installations. Multicomponent mixtures are a combination of substances of different physical nature. These include not only gas-liquid flows, but also, for example, mixtures of air and sand, water and oil. The paper presents the main attention is paid to the movement of two-phase flows in the pipeline."

Optimization of the Pressure Drop Prediction Model of Wellbore Multiphase Flow Based on Simultaneous Perturbation Stochastic Approximation

In the process of gas lift design and condition diagnosis, the accuracy and timeliness of wellbore multiphase flow model prediction results are the basis for all subsequent work. However, for the commonly used wellbore multiphase flow pressure drop prediction models, there is a big deviation between the predicted value and the measured one, and the optimization based on the measured data is time-consuming, and it is difficult to obtain the optimal parameters of the model. Therefore, based on the well bore pressure distribution data measured quickly in area R of an oil field in Kazakhstan, a better prediction model of multiphase flow in the well bore was selected at first. Then, the simultaneous perturbation stochastic approximation (SPSA) algorithm was incorporated in the wellbore multiphase flow model to optimize the liquid holdup, which is the leading factor in the model. After repeated single well optimization and greedy selection, the optimal parameters suitable for the whole block were obtained. The example shows that the optimization speed is 10 times faster than that of Particle Swarm Optimization (PSO). After that, the optimized model was used to predict the wellbore pressure distribution, and it was found that the relative error between the measured value and the predicted one was less than 15%.

Analisa Unjuk Kerja Sucker Rod Pump C-228 D – 213 – 86-7466 Sebagai Metode Pengangkatan Buatan Produksi Minyak Bumi untuk API 15° dan 45°

The oil production process is the process of extracting oil from the reservoir using the wells that have been made. In the production process there are three stages, namely primary recovery, secondary recovery and tertiary recovery. At the primary recovery stage there are two methods, namely production using natural reservoir energy (natural flow) and production using artificial lift methods (artificial lift). There are two basic principles of artificial lift, namely gas lift and pumps. The principle of the gas lift is to inject gas into the bottom of the well thereby reducing the density and pressure gradient of the reservoir fluid so that the fluid flows more easily. While the principle of the pump is to provide additional energy (head) to lift the fluid. The type of pump that is often used for shallow wells is Sucker Rod Pump. The performance of the sucker rod pump is influenced by the characteristics of the well and reservoir such as pressure, well productivity, physical properties of the fluid, as well as the depth of the well and the dimensions of the sucker rod pump. In this study, the factors studied were the physical properties of the fluid, namely the API of the fluid with variations of API 15o and API 45o, as well as the pump volumetric efficiency (Ev) of 90% and 70%. From the analysis carried out, the results obtained a). For API 15° and Ev 90% fluids: 759 stb/day and 39 hp prime mover power; and for API 15° and Ev 70%: 591 stb/day and prime mover power of 32.2 hp. b). For API 45° and Ev 90% fluids: 783 stb/day and prime mover power of 34.3 hp; and for API 45° and Ev 70%: 609 stb/day and prime mover power of 28.6 hp.