scholarly journals The EVALUATION AND OPTIMIZATION OF ELECTRICAL SUBMERSIBLE PUMP WELLS THAT HAVE A HIGH PI USING VARIABLE SPEED DRIVE WITH FREQUENCY ABOVE 60HZ IN "X" FIELD "Y" WELLS (EVALUASI DAN OPTIMISASI SUMUR ELECTRICAL SUBMERSIBLE PUMP YANG MEMILIKI PI TINGGI DENGAN MENG

2021 ◽  
Vol 4 (02) ◽  
Author(s):  
Rycha Melysa
Keyword(s):  
Oil Industry ◽  
Submersible Pump ◽  
Production Potential ◽  
Artificial Lift ◽  
Natural Flow ◽  
Production Wells ◽  
Fluid Production ◽  
Electrical Submersible Pump ◽  
Electric Submersible Pump ◽  
Selection Of

The condition of a well if it is produced continuously will cause reservoir pressure to fall, and the flow rate will also go down, as a result the productivity of the well will also decrease. For this reason, there is a need for energy that can help lift fluid up to the surface. In the primary method there are 2 stages of production, namely natural flow where oil is raised directly through the tubing surface, and artificial lift is the method of obtaining oil by using the aid of additional tools. In the oil industry there are various types of artificial lifts, one of which is an electric submersible pump (ESP).   Electric Submersible Pump is an electric pump that is immersed into a liquid. This pump is made on the basis of a multilevel centrifugal pump where each level has an impeller and iffuser which aims to push the fluid to the surface. ESP planning is strongly influenced by the roductivity of production wells. The rate of fluid production influences the selection of pump type and size. This is because each pump has its own production rate based on the type and size of each pump used.   In the course of producing oil, there will certainly be a problem that will cause a decline in production, therefore it is necessary to evaluate and redesign the ESP pump, in an effort to optimize the production potential of these wells. In this study an evaluation of the performance of the electrical submersible pump will be carried out and a pump redesigned to optimize production using AutographPC software on the well X in the field Y Kondisi suatu sumur jika diproduksikan terus-menerus akan mengakibatkan tekananreservoir turun, dan laju alir akan turun pula, akibatnya produktivitas sumur akan turunjuga. Untuk itu perlu adanya tenaga yang dapat membantu mengangkat fluida sampaikepermukaan. Dalam metode primer terdapat 2 tahapan produksi yaitu natural flowdimana minyak terangkat kepermukaan langsung melalu tubing, dan artificial liftmerupakan metode perolehan minyak dengan menggunakan bantuan alat tambahan.Dalam dunia perminyakan ada berbagai macam jenis pengangkatan buatan salahsatunya adalah electric submersible pump (ESP). Electric Submersibel Pump merupakan pompa listrik yang dibenamkan kedalam cairan.Pompa ini dibuat atas dasar pompa sentrifugal bertingkat banyak dimana setiap tingkatmempunyai impeller dan diffuser yang bertujuan untuk mendorong fluida kepermukaan.Perencanaan ESP sangat dipengaruhi oleh produktivitas sumur produksi. Laju produksifluida berpengaruh terhadap pemilihan jenis dan ukuran pompa. Hal ini dikarenakantiap-tiap pompa memiliki laju produksi sendiri berdasarkan jenis dan ukuran tiap- tiappompa yang dipakai. Dalam kegiatan memproduksikan minyak tentu suatu saat akan terjadi permasalahanyang mengakibatkan menurunnya produksi, Oleh karena itu perlu dilaksanakan evaluasidan design ulang pompa ESP, sebagai upaya untuk mengoptimalkan potensi produksisumur-sumur tersebut. Pada penelitian ini akan dilakukan evaluasi kinerja electricalsubmersible pump dan melakukan desain ulang pompa untuk optimasi produksidengan menggunakan software AutographPC pada sumur X lapangan y Kata kunci: electric submersible pump, AutographPC, laju produksi

scholarly journals OPTIMASI PRODUKSI SUMUR EC-6 DENGAN MEMBANDINGKAN PENGANGKATAN BUATAN GAS LIFT DAN ELECTRIC SUBMERSIBLE PUMP

PETRO ◽  
2019 ◽  
Vol 8 (1) ◽  
pp. 8
Author(s):  
Jonathan Jonathan ◽  
Sisworini Sisworini ◽  
Samsol Samsol ◽  
Hari Oetomo
Keyword(s):  
Production System ◽  
Gas Injection ◽  
Pipe Diameter ◽  
Submersible Pump ◽  
Reservoir Stimulation ◽  
Artificial Lift ◽  
Sucker Rod ◽  
Electrical Submersible Pump ◽  
Gas Lift ◽  
Electric Submersible Pump

<em>In the world of oil is very common in the production system. This production system produces oil from wells after drilling and well compressions. Over time, the production of a well may decrease due to several parameters of pressure drop and the presence of clay which makes the pipe diameter narrower. There are several methods used to increase the decrease in production including adding artificial lifts such as sucker rod pump, electric submersible pump and gas lift, reservoir stimulation and pipe cleaning if the pipe diameter is reduced due to clay. The well has been installed an artificial lift is a gas lift and this well need an optimization to increase its production. The EC-6 well optimization is planned by comparing the lift-up scenario of the gas lift by adjusting the rate of gas injection and deepening the orifice injection and also an installation of electrical submersible pump. Best percentage of optimization production from EC-6 Well, last scenario is chosen which is new installation artificial lift ESP from gas lift (existing) and gaining 18.52% form existing production</em>

scholarly journals Production Data Analysis and Sonolog for Determining Artificial Lift Design and Well Characteristic

2020 ◽  
Vol 1 (1) ◽  
pp. 28
Author(s):  
Bambang Bintarto ◽  
Rizky Rahmat Auliya ◽  
Riza Andhika Mahendra Putra ◽  
Afif Surya Pradipta ◽  
Rafli Arie Kurnia
Keyword(s):  
Produced Water ◽  
Submersible Pump ◽  
Water Control ◽  
Injection Wells ◽  
Diagnostic Plot ◽  
Artificial Lift ◽  
Production Wells ◽  
Production History ◽  
Electric Submersible Pump

Tarakan Field, North Kalimantan is a part of PT. Pertamina EP Asset 5. The Tarakan Field has 5 structures in the form of Pamusian, Juata, Sesanip, Mangatal, and Sembakung. The Tarakan Field has 57 production wells and 6 injection wells. The wells at Tarakan field are produced with artificial lifts in the form of Sucker Rod Pump (SRP) totaling 25, Hydraulic Pumping Unit (HPU) totaling 11, Electric Submersible Pump (ESP) totaling 19 and Progressive Cavity Pump (PCP) totaling 2. The determination of artificial lifts is carried out by the design of well characteristics and production history. The design at Tarakan Field was carried out with an artificial lift in the form of ESP (Electric Submersible Pump). ESP is used according to reservoir and formation characteristics in Tarakan Field. Water Control Diagnostic Plot is a method used to analyze the effect of control on produced water. Water Control Diagnostic plot is plot between WOR and WOR derivative vs time. The plot was carried out on a log-log scale. The plot on the Water Control Diagnostic Plot is then analyzed against the graph created by the KS Chan. So from the analyzed plot, it is found whether or not there is a problem in the well at Tarakan Field. The results of the graph analysis on the well at Tarakan Field on the chart show that the field does not indicate a problem. Keywords: chan plot; design; esp; production

Pushing 30 Years Multiple Brown Fields Limits Through Artificial Lift and Facilities Improvement

2021 ◽  
Author(s):  
Mohd Hafizi Ariffin ◽  
Muhammad Idraki M Khalil ◽  
Abdullah M Razali ◽  
M Iman Mostaffa
Keyword(s):  
New Technology ◽  
Lessons Learned ◽  
Oil Fields ◽  
Submersible Pump ◽  
Large Space ◽  
Gas Well ◽  
Wellhead Pressure ◽  
Artificial Lift ◽  
Electrical Submersible Pump ◽  
Gas Lift

Abstract Most of the oil fields in Sarawak has already producing more than 30 years. When the fields are this old, the team is most certainly facing a lot of problems with aging equipment and facilities. Furthermore, the initial stage of platform installation was not designed to accommodate a large space for an artificial lift system. Most of these fields were designed with gas lift compressors, but because of the space limitation, the platforms can only accommodate a limited gas lift compressor capacity due to space constraints. Furthermore, in recent years, some of the fields just started with their secondary recovery i.e. water, gas injection where the fluid gradient became heavier due to GOR drop or water cut increases. With these limitations and issues, the team needs to be creative in order to prolong the fields’ life with various artificial lift. In order to push the limits, the team begins to improve gas lift distribution among gas lifted wells in the field. This is the cheapest option. Network model recommends the best distribution for each gas lifted wells. Gas lifted wells performance highly dependent on fluid weight, compressor pressure, and reservoir pressure. The change of these parameters will impact the production of these wells. Rigorous and prudent data acquisitions are important to predict performance. Some fields are equipped with pressure downhole gauges, wellhead pressure transmitters, and compressor pressure transmitters. The data collected is continuous and good enough to be used for analysis. Instead of depending on compressor capacity, a high-pressure gas well is a good option for gas lift supply. The issues are to find gas well with enough pressure and sustainability. Usually, this was done by sacrificing several barrels of oil to extract the gas. Electrical Submersible Pump (ESP) is a more expensive option compared to a gas lift method. The reason is most of these fields are not designed to accommodate ESP electricity and space requirements. Some equipment needs to be improved before ESP installation. Because of this, the team were considering new technology such as Thru Tubing Electrical Submersible Pump (TTESP) for a cheaper option. With the study and implementation as per above, the fields able to prolong its production until the end of Production Sharing Contract (PSC). This proactive approach has maintained the fields’ production with The paper seeks to present on the challenges, root cause analysis and the lessons learned from the subsequent improvement activities. The lessons learned will be applicable to oil fields with similar situations to further improve the fields’ production.

Corrosion Challenges on Electrical Submersible Pump Wells in the North Kuwait Field

2021 ◽  
Author(s):  
Abdullatif Al-Majdli ◽  
Carlos Caicedo Martinez ◽  
Sarah Al-Dughaishem
Keyword(s):  
Submersible Pump ◽  
Stray Current ◽  
The North ◽  
Artificial Lift ◽  
Steel Tubing ◽  
Electrical Submersible Pump ◽  
Historic Data ◽  
Corrosion Resistant Alloy ◽  
Galvanic Couples ◽  
Sweet Corrosion

Abstract Oil production in North Kuwait (NK) asset highly relies on artificial lift systems. The predominant method of artificial lift in NK is electrical submersible pump (ESP). Corrosion is one of the major issues for wells equipped with ESP in NK field. Over 20% of the all pulled ESPs in 2019 and 2020 in NK field were due to corrosion of the completion or the ESP string. With an increase in ESP population in NK, a proactive corrosion mitigation is essential to reduce the number of ESP wells requiring workover. Historic data of the pulled ESPs in NK revealed that most of the corrosion cases were found in the tubing as opposed to the ESP components. Although there are multiple factors that can cause corrosion in NK, the driving force was identified to be the presence of CO2 (sweet corrosion). Corrosion rates have been enhanced by other factors such as stray current and galvanic couples. In this paper, multiple methods have been suggested to minimize and prevent the corrosion issue such as selecting the optimal completion and ESP metallurgy (ex. corrosion resistant alloy), installing internally glass reinforced epoxy lined carbon steel tubing, and installing a sacrificial anode whenever applicable.

Experimental Study and Modeling of Heating Effect in Electrical Submersible Pump Operating With Ultra-Heavy Oil

2018 ◽  
Author(s):  
Jorge Luiz Biazussi ◽  
Cristhian Porcel Estrada ◽  
William Monte Verde ◽  
Antonio Carlos Bannwart ◽  
Valdir Estevam ◽  
...  
Keyword(s):  
Heavy Oil ◽  
Critical Factor ◽  
High Viscosity ◽  
Inlet Temperature ◽  
Outlet Temperature ◽  
Heating Effect ◽  
Submersible Pump ◽  
Oil Viscosity ◽  
Artificial Lift ◽  
Electrical Submersible Pump

A notable trend in the realm of oil production in harsh environments is the increasing use of Electrical Submersible Pump (ESP) systems. ESPs have even been used as an artificial-lift method for extracting high-viscosity oils in deep offshore fields. As a way of reducing workover costs, an ESP system may be installed at the well bottom or on the seabed. A critical factor, however, in deep-water production is the low temperature at the seabed. In fact, these low temperatures constitute the main source for many flow-assurance problems, such as the increase in friction losses due to high viscosity. Oil viscosity impacts pump performance, reducing the head and increasing the shaft power. This study investigates the influence of a temperature increase of ultra-heavy oil on ESP performance and the heating effect through a 10-stage ESP. Using several flow rates, tests are performed at four rotational speeds and with four viscosity levels. At each rotational speed curve, researchers keep constant the inlet temperature and viscosity. The study compares the resulting data with a simple heat model developed to estimate the oil outlet temperature as functions of ESP performance parameters. The experimental data is represented by a one-dimensional model that also simulates a 100-stage ESP. The simulations demonstrate that as the oil heat flows through the pump, the pump’s efficiency increases.

scholarly journals Electrical Submersible Pump Design in Vertical Oil Wells

2020 ◽  
Vol 4 (4) ◽  
pp. 1-7
Author(s):  
Gomaa S
Keyword(s):  
Oil Wells ◽  
Maintenance Cost ◽  
Oil Well ◽  
Submersible Pump ◽  
Reservoir Properties ◽  
Pump Design ◽  
Artificial Lift ◽  
Complete Study ◽  
Electrical Submersible Pump

Artificial Lift is a very essential tool to increase the oil production rate or lift the oil column in the wellbore up to the surface. Artificial lift is the key in case of bottom hole pressure is not sufficient to produce oil from the reservoir to the surface. So, a complete study is carried to select the suitable type of artificial lift according to the reservoir and wellbore conditions like water production, sand production, solution gas-oil ratio, and surface area available at the surface. Besides, the maintenance cost and volume of produced oil have an essential part in the selection of the type of artificial lift tool. Artificial lift tools have several types such as Sucker Rod Pump, Gas Lift, Hydraulic Pump, Progressive Cavity Pump, Jet Pump, and Electrical Submersible Pump. All these types require specific conditions for subsurface and surface parameters to apply in oil wells. This paper will study the Electrical Submersible Pump “ESP” which is considered one of the most familiar types of artificial lifts in the whole world. Electrical Submersible Pump “ESP” is the most widely used for huge oil volumes. In contrast, ESP has high maintenance and workover cost. Finally, this paper will discuss a case study for the Electrical Submersible pump “ESP” design in an oil well. This case study includes the entire well and reservoir properties involving fluid properties to be applied using Prosper software. The results of the design model will impact oil productivity and future performance of oil well.

scholarly journals Pemilihan Pompa Electric Submersible Pump Menggunakan Metode Analytical Hierarchy Process (Studi Kasus Lapangan Zaryka)

2014 ◽  
Vol 3 (1) ◽  
pp. 9-18
Author(s):  
Muhammad Ariyon
Keyword(s):  
Analytical Hierarchy Process ◽  
Submersible Pump ◽  
Artificial Lift ◽  
Group 16 ◽  
Hierarchy Process ◽  
Electric Submersible Pump

Lapangan Zaryka merupakan salah satu lapangan minyak pada cekungan Sumatera Tengah. Untuk meningkatkan produksi minyaknya, digunakan pompa benam listrik bawah permukaan (Electric Submersible Pump). Pompa ESP merupakan salah satu jenis artificial lift yang digunakan untuk memproduksikan minyak bumi ke permukaan. Permasalahannya, terdapat berbagai produk ESP yang dipasarkan dengan berbagai jenis,k tipe, dan keunggulan yang bervariasi. Keberagaman ini menyulitkan bagi perusahaan untuk menentukan produk pompa ESP mana yang tepat untuk digunakan. Metode Analytical Hierarchy Process dapat dipergunakan untuk membantu dalam memilih pompa ESP. Terdapat tiga faktor utama yang menjadi pertimbangan yaitu daya tahan produk, pengalaman dan reputasi dan jumlah maintenance, sementara untuk elemen alternatif terdapat empat produk pompa yaitu Centraleft, Motherford, Red-A dan Wooden Group. Hasil analisa menunjukkan bahwa faktor utama yang menjadi pertimbangan dalam pemilihan pompa ESP adalah faktor daya tahan produk (56%), faktor jumlah maintanance (32%), dan faktor pengalaman dan reputasi (12%). Ditinjau dari berbagai faktor, alternatif pompa Red-A merupakan alternatif pompa terbaik (35%), pompa Centraleft (29%), pompa Motherford (19%) dan pompa Wooden Group (16%).

scholarly journals Rigorous review of electrical submersible pump failure mechanisms and their mitigation measures

2021 ◽  
Vol 11 (10) ◽  
pp. 3799-3814
Author(s):  
Sherif Fakher ◽  
Abdelaziz Khlaifat ◽  
M. Enamul Hossain ◽  
Hashim Nameer
Keyword(s):  
Oil Recovery ◽  
Failure Mechanisms ◽  
Mitigation Measures ◽  
Submersible Pump ◽  
Personal Safety ◽  
Optimum Conditions ◽  
Pump Failure ◽  
Artificial Lift ◽  
Electrical Submersible Pump ◽  
Mitigation Methods

AbstractArtificial lift is a vital part of the life of many oil wells worldwide. Using several artificial lift methods can prolong the life of the wells and increase oil recovery significantly. One of the most applied artificial lift methods nowadays is the electrical submersible pump (ESP). This artificial lift method has the ability to handle large volumes of hydrocarbons and is applicable under many conditions in both offshore and onshore reservoirs. Even though ESP has been applied extensively for many years, it still suffers from many failures due to electrical, mechanical, and operational problems associated with the ESP downhole assembly. Understanding the main reasons behind ESP failures and how to rapidly and effectively avoid and mitigate these failures is imperative to reduce cost and damage and improve operational and rig-personal safety. This research performs a comprehensive review on ESP failure mechanisms and analyzes these failures in order to determine the optimum conditions to operate the ESP. This can help minimize and avoid these failures. Also, should these failures occur, the research proposes several mitigation methods for each failure based on analysis of different field cases worldwide.

Successful Application of Rigless Fully Retrievable ESP System in Bohai Offshore Oilfield, China

2021 ◽  
Author(s):  
Baobing Shang ◽  
Junfei Li ◽  
Tao Fang ◽  
Fahao Yu ◽  
Xiaodong Han
Keyword(s):  
Water Source ◽  
Oil Wells ◽  
Power Cable ◽  
Submersible Pump ◽  
Artificial Lift ◽  
New Type ◽  
Technical Details ◽  
The Common ◽  
Electric Submersible Pump ◽  
New System

Abstract In bohai offshore oilfield, about 98% oil wells produce with electric submersible pump (ESP). For the common ESP system, workover is needed to replace the failed pump about every 4 years, resulting in significant operation cost and production lost. To solve this problem, a new type of rigless fully retrievable electric submersible pump (RFR-ESP) is developed and applied in bohai oilfield. This paper mainly introduces the technical details of the used RFR-ESP system, and the real application effects in typical wells. This new system consists of downhole permanent part and retrievable part, with the power cable clamed externally along with the tubing. The core of the system is a specially designed wet connector system. Through this connector, any ESP manufacture's equipment can be used. For this technology, the retrieval of ESP can be finished by standard oilfield wireline operation, and no rig workover is required any more. Till now, two different systems suitable for 7″ tubing and 5-1/2″ tubing have been developed in order to meet the yield of different wells. Bohai oilfield installed the first RFR-ESP in 2013. Up to now, 6 wells have applied this technology, including one water source well and five oil wells. The longest running time of the ESP is about 2000 days, and it is still in service now. The maximum liquid production is about 2800m3/d. For this new system, the workover time of ESP replacement reduces from 10 days to about 2 days comparing to the traditional rig workover process, and the number of the workover operators reduces from 30 to about 10. All of these are helpful to reduce the workover cost and the production lost. Besides, several problems encountered in the wells, such as power cable failure provides valuable field experience for the promoted application in bohai offshore oilfield. The successful application of this technology indicates that it has the potential to lower ESP operating costs, and even improve the artificial lift status of offshore oilfield. What's more, this new system is expected to be used in unmanned platform, thus no workover boat is needed any more, which will drastically cut down the development cost.

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