Control system for increasing oil production rate at an oil field with the use of artificial intelligence

Abstract The ultimate goal of oilfield development is to maximize the investment benefits. The reservoir performance prediction is directly related to oilfield investment and management. The traditional strategy based on numerical simulation has been widely used with the disadvantages of long run time and much information needed. It is necessary to form a fast and convenient method for the oil production prediction, especially for layered reservoir. A new method is proposed to predict the development indexes of multi-layer reservoirs based on the injection-production data. The new method maintains the objectivity of the data and demonstrates the superiority of the intelligent algorithm. The layered reservoir is regarded as a series of single layer reservoirs on the vertical direction. Considering the starting pressure gradient of non-Newtonian fluid flow and the variation of water content in the oil production index, the injection-production response model for single-layer reservoirs is established. Based on that, a composite model for the multi-layer reservoir is established. For model solution, particle swarm optimization is applied for optimization of the new model. A heterogeneous multi-layer model was established for validation of the new method. The results obtained from the new proposed model are in consistent with the numerical simulation results. It saves a lot of computing time with the incorporation of the artificial intelligence methods. It showed that this technique is valid and effective to predict oil performance in layered reservoir. These examples showed that the application of big data and artificial intelligence method is of great significance, which not only shortens the working time, but also obtains relatively higher accuracy. Based on the objective data of the oil field and the artificial intelligence algorithm, the prediction of oil field development data can be realized. This technique has been used in nearly 100 wells of Bohai oilfields. The results showed in this paper reveals that it is possible to estimate the production performance of the water flooding reservoirs.

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Fracture Treatment Design in the Lower Miocene Reservoir, Offshore Viet Nam

10.2118/201056-ms ◽

2021 ◽

Author(s):

Truong Nguyen Huu

Keyword(s):

Production Rate ◽

Oil Production ◽

High Water ◽

Oil Field ◽

Base Case ◽

Fracture Conductivity ◽

Lower Miocene ◽

High Water Cut ◽

Water Cut ◽

Fractured Well

Abstract In the past decades, most oil explotation in the White Tiger oil field was produced from the basement reservoir. However, in recent years, these pay zones consist of basement reservoirs, Oligocene reservoirs, and Miocene reservoirs of which oil field s have been declined in oil production rate due to several issues such as complex fracture network, high heterogeneity formation, high water cut, and the reduction of reservoir pressure. The huge issues in the most production wells at basement reservoir were high water cut and it has been significantly increasing during oil production yearly. Therefore, the total amount of oil production in all pay zones sharply decreased with time. At present, the lower Miocene reservoir is one of the best tight oil reservoirs to produce oil extractrion. The lower Miocene reservoir has been faced some issues such as high heterogeneity, complex structure, catastrophic clay swelling, low connectivity among the fractures, low effective wellbore radius and the reservoir that is hig h temperature up to 120°C, the closure pressure up to 6680psi, reservoir pressure up to 4500 psi, reservoir depth up to 3000m. Another reason low conductivity consists of both low reservoir porosity ranging from 1% of the hard shale to 10% of the sandstone formation, and the low permeability raining from 1md to 10md. By considering the various recovery methods, the integrated hydraulic fracturing stimulation is the best tool to successfully stimulate this reservoir, which method allows an increase in oil production rate. In the post fractured well has been shown an increase in productivity over 3 folds in comparison with the base case with fracture half-length nearly 75m, and fracture conductivity about 5400md.ft, which production rate is higher than the production rate of the base case. In addition, the proppant mass is used of 133,067 lbs of which the first main stage is to pump sinter lite bauxite proppant type of 20/40 into the fractures and the next big stage is to pump sintered ball bauxite proppant size of 16/30 into the fractures, which not only isolate proppant flow back but also increase fracture conductivity at the near wellbore as wel as high productivity rate after fractured well. To improve proppant transport, fract uring fluid systems consist of Guar polymer concentration of 11.2 pptg with these additives to form a total leak-off coefficient of 0.00227 ft/min0.5.

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Application of the bottomhole pressure calculation method to operate an oil well

Oil and Gas Studies ◽

10.31660/0445-0108-2019-1-73-81 ◽

2019 ◽

pp. 73-81

Author(s):

Natalya N. Аlaeva ◽

Yury B. Тоmus

Keyword(s):

Control System ◽

Process Control ◽

Calculation Method ◽

Oil Production ◽

Process Control System ◽

Oil Field ◽

Oil Well ◽

System A ◽

Pressure Calculation ◽

Bottomhole Pressure

The aim of the study is to obtain reliable values of bottomhole pressure calculation method in oil wells of PJSC «Tatneft» due to technical difficulties emerged when performing deep measurements of producing wells at the Romashkino oil field.We have performed calculations of bottomhole pressure in wells according to Hasan — Kabir method and the RD 153-39.0-920-15 method. The comparison of the obtained values revealed that the average relative error of Hasan — Kabir method is 5,33 % (not more than 10 %), in contrast to the RD method.Also, we have created the model of the process control system of oil production in the program MATLAB/Simulink. This program includes the algorithm of regulation the liquid rate. In modeling the control system, a transient process is observed, in which the value of the liquid rate increases and stabilizes. Thus, the application of Hasan — Kabir method in the proposed process control system of oil production is possible in all wells at the Romashkino oil field.

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Process Design of Cyclic Water Flooding by Real-Time Monitoring

Journal of Energy Resources Technology ◽

10.1115/1.4040525 ◽

2018 ◽

Vol 140 (11) ◽

Cited By ~ 1

Author(s):

Kobra Pourabdollah

Keyword(s):

Real Time ◽

Production Rate ◽

Process Design ◽

Water Injection ◽

Oil Production ◽

Oil Field ◽

Water Flooding ◽

Injection System ◽

Real Time Monitoring ◽

Naturally Fractured

The gradual decline in the oil production rate of water flooded reservoirs leads to decrease in the profit of water flooding system. Although cyclic water injection (CWI) was introduced to reduce the descending trend of oil production in water flooded reservoirs, it must be optimized based upon the process parameters. The objective of this study is to develop all process design criteria based upon the real-time monitoring of CWI process in a naturally fractured reservoir having five producing wells and five injector wells completed in an Arab carbonated formation containing light crude oil (API = 42 deg). For this aim, a small pilot oil field was selected with water injection facilities and naturally producing oil wells and all data were collected from the field tests. During a five years' field test, the primary observations at the onset of shutdown periods of the water injection system revealed a repeatable significant enhancement in oil production rate by a factor of plus 5% leading us to assess the application of CWI. This paper represents the significant parameters of pressure and productivity affected during CWI in naturally fractured carbonate reservoirs based upon a dual porosity generalized compositional model. The results hopefully introduce other oil producer companies to the potential of using CWI to increase oil production in conventional water injection systems. The results also outline situations where such applications would be desirable.

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Efficiency Analysis of the Geological-Technical Activities in Severo-Ostrovnoe Field

Journal of Computational and Theoretical Nanoscience ◽

10.1166/jctn.2019.8359 ◽

2019 ◽

Vol 16 (11) ◽

pp. 4584-4588

Author(s):

I. A. Pogrebnaya ◽

S. V. Mikhailova

Keyword(s):

Hydraulic Fracturing ◽

Production Rate ◽

Oil Recovery ◽

Oil Production ◽

Horizontal Wells ◽

Oil Field ◽

Field Development ◽

Multi Stage ◽

Field Works ◽

Technical Measures

The work is devoted to identifying the most relevant geological and technical measures carried out in Severo-Ostrovnoe field from the period of its development to the present. Every year dozens of geotechnical jobs (GJ) are carried out at each oil field-works carried out at wells to regulate the development of fields and maintain target levels of oil production. Today, there are two production facilities in the development of the Severo-Ostrovnoe field: UV1a1 and BV5. With the help of geotechnical jobs, oil-producing enterprises ensure the fulfillment of project indicators of field development (Mikhailov, N.N., 1992. Residual Oil Saturation of Reservoirs Under Development. Moscow, Nedra. p.270; Good, N.S., 1970. Study of the Physical Properties of Porous Media. Moscow, Nedra. p.208). In total, during the development of the Severo-Ostrovnoe field, 76 measures were taken to intensify oil production and enhance oil recovery. 12 horizontal wells were drilled (HW with multistage fracking (MSF)), 46 hydraulic fracturing operations were performed, 12 hydraulic fracturing operations were performed at the time of withdrawal from drilling (HW with MSF), five sidetracks were cut; eight physic-chemical BHT at production wells; five optimization of well operation modes. The paper analyzes the performed geological and technical measures at the facilities: UV1a1∦BV5 of the Severo-Ostrovnoe field. Four types of geological and technical measures were investigated: hydraulic fracturing, drilling of sidetracks with hydraulic fracturing, drilling of horizontal wells with multi-stage hydraulic fracturing, and physic-chemical optimization of the bottom-hole formation zone. It was revealed that two geotechnical jobs, namely, formation hydraulic fracturing (FHF) and drilling of lateral shafts in the Severo-Ostrovnoe field are the most highly effective methods for intensifying reservoir development and increasing oil recovery. SXL was conducted at 5 wells. The average oil production rate is 26.6 tons per day, which is the best indicator. Before this event, the production rate of the well was 2.1 tons per day. Currently, the effect of ongoing activities continues.

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Selection of effective wax (deposition) inhibitors to oil production and transportation at the Kondinskoye oil field

Oil and Gas Studies ◽

10.31660/0445-0108-2020-2-120-127 ◽

2020 ◽

pp. 120-127

Author(s):

E. N. Skvortsova ◽

O. P. Deryugina

Keyword(s):

Laboratory Tests ◽

Initial Dosage ◽

Oil Production ◽

Oil Field ◽

Transport Systems ◽

Asphaltene Precipitation ◽

Wax Deposition ◽

Selection Of ◽

Pilot Tests

The article discusses the results of a study on the selection of wax inhibitors that can be used at the Kondinskoye oil field during transportation and dehydration of the emulsion.Asphaltene precipitation is one of the most serious issues in oil production. The experiment was conducted in order to select the most effective wax inhibitors. We have carried out laboratory tests to choose the most effective wax inhibitor in the conditions of oil production, collection, preparation and external transport systems at the Kondinskoye oil field. Based on the data obtained, wax inhibitor-2, wax inhibitor-4, and wax inhibitor-6 have shown the best results in ensuring the efficiency of inhibition, which should be at least 70 %, and, therefore, they can be allowed to pilot tests. The recommended initial dosage of inhibitors according to the results obtained during pilot tests should be at least 500 g/t of oil.

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Study and Comparison of Vibration-Based Intrusive and Non-Intrusive Sand Monitoring System

Advanced Materials Research ◽

10.4028/www.scientific.net/amr.701.440 ◽

2013 ◽

Vol 701 ◽

pp. 440-444

Author(s):

Gang Liu ◽

Peng Tao Liu ◽

Bao Sheng He

Keyword(s):

Real Time ◽

Monitoring System ◽

Oil Production ◽

Oil Wells ◽

Oil Field ◽

Sand Production ◽

The Status

Sand production is a serious problem during the exploitation of oil wells, and people put forward the concept of limited sand to alleviate this problem. Oil production with limited sanding is an efficient mod of production. In order to complete limited sand exploitation, improve the productivity of oil wells, a real-time sand monitoring system is needed to monitor the status of wells production. Besides acoustic sand monitoring and erosion-based sand monitoring, a vibration-based sand monitoring system with two installing styles is proposed recently. The paper points out the relationships between sand monitoring signals collected under intrusive and non-intrusive installing styles and sanding parameters, which lays a good foundation for further study and actual sand monitoring in oil field.

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Increasing Wells Lifetime by Using PAR VALVE to Overcome Sand Settling Problems at Pertamina EP Asset 1 Field Jambi

10.29118/ipa21-e-62 ◽

2021 ◽

Author(s):

A. S. Ramadhan

Keyword(s):

Oil Production ◽

Oil Field ◽

Average Lifetime ◽

Sand Production ◽

Maintenance And Repair ◽

Engine Maintenance

In the Jambi oil field, sand production can create unattainable production targets and short-lived well lifetime. One function of the Jambi Engineering and Planning Field is to look for solutions to these problems, such as the installation of progressive cavity pumps (PCP) into wells. Although successful, a problem that often arises in PCP wells is sand settling when the PCP is off, for example during electric trips, engine maintenance and repair of flowlines. This settling can lead to a stuck PCP. A recent solution has been to install a Pressure Actuated Relief (PAR) valve, where the tool directs sand deposits out of the tubing to the annulus so that it does not enter the pump. Installation of this tool has increased the average lifetime of sandy wells from 2 months to 6 months, and has increased oil production in these wells by up to 47%.This paper will discuss the successful installation of a PAR Valve into well KTT-08 in the Jambi Field.

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Unlocking By-Passed Oil with Autonomous Inflow Control Devices Through an Integrated Approach

10.2118/207569-ms ◽

2021 ◽

Author(s):

Pawan Agrawal ◽

Sharifa Yousif ◽

Ahmed Shokry ◽

Talha Saqib ◽

Osama Keshtta ◽

...

Keyword(s):

Continuous Production ◽

Oil Production ◽

Gas Production ◽

Oil Field ◽

Production Performance ◽

Fluid Distribution ◽

Flow Profile ◽

Horizontal Drain ◽

Control Devices

Abstract In a giant offshore UAE carbonate oil field, challenges related to advanced maturity, presence of a huge gas-cap and reservoir heterogeneities have impacted production performance. More than 30% of oil producers are closed due to gas front advance and this percentage is increasing with time. The viability of future developments is highly impacted by lower completion design and ways to limit gas breakthrough. Autonomous inflow-control devices (AICD's) are seen as a viable lower completion method to mitigate gas production while allowing oil production, but their effect on pressure drawdown must be carefully accounted for, in a context of particularly high export pressure. A first AICD completion was tested in 2020, after a careful selection amongst high-GOR wells and a diagnosis of underlying gas production mechanisms. The selected pilot is an open-hole horizontal drain closed due to high GOR. Its production profile was investigated through a baseline production log. Several AICD designs were simulated using a nodal analysis model to account for the export pressure. Reservoir simulation was used to evaluate the long-term performance of short-listed scenarios. The integrated process involved all disciplines, from geology, reservoir engineering, petrophysics, to petroleum and completion engineering. In the finally selected design, only the high-permeability heel part of the horizontal drain was covered by AICDs, whereas the rest was completed with pre-perforated liner intervals, separated with swell packers. It was considered that a balance between gas isolation and pressure draw-down reduction had to be found to ensure production viability for such pilot evaluation. Subsequent to the re-completion, the well could be produced at low GOR, and a second production log confirmed the effectiveness of AICDs in isolating free gas production, while enhancing healthy oil production from the deeper part of the drain. Continuous production monitoring, and other flow profile surveys, will complete the evaluation of AICD effectiveness and its adaptability to evolving pressure and fluid distribution within the reservoir. Several lessons will be learnt from this first AICD pilot, particularly related to the criticality of fully integrated subsurface understanding, evaluation, and completion design studies. The use of AICD technology appears promising for retrofit solutions in high-GOR inactive strings, prolonging well life and increasing reserves. Regarding newly drilled wells, dedicated efforts are underway to associate this technology with enhanced reservoir evaluation methods, allowing to directly design the lower completion based on diagnosed reservoir heterogeneities. Reduced export pressure and artificial lift will feature in future field development phases, and offer the flexibility to extend the use of AICD's. The current technology evaluation phases are however crucial in the definition of such technology deployments and the confirmation of their long-term viability.

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