scholarly journals Optimation Pressure Loss to Oil Production System with Electrical Submersible Pump (ESP) at the Well A SW Field Bojonegoro, East Java

2017 ◽  
Vol 877 ◽  
pp. 012069
Author(s):  
A M Ilmah ◽  
L Hendrajaya
Keyword(s):  
Production System ◽  
Pressure Loss ◽  
Oil Production ◽  
Submersible Pump ◽  
Electrical Submersible Pump

Hybrid Electrical-Submersible-Pump/Gas-Lift Application to Improve Heavy Oil Production: From System Design to Field Optimization

2021 ◽  
pp. 1-28
Author(s):  
Son Tran ◽  
Vu Le
Keyword(s):  
Service Life ◽  
Power Consumption ◽  
Heavy Oil ◽  
Oil Production ◽  
Production Optimization ◽  
Submersible Pump ◽  
Hybrid Mode ◽  
Field Development ◽  
Electrical Submersible Pump ◽  
Gas Lift

Abstract The typical challenge encountered in developing heavy-oil reservoirs is inefficient wellbore lifting caused by complex multiphase flows. The literature on modeling of a hybrid artificial lift (AL) system is relatively sparse and these works typically model the AL system on the basis of individual AL methods. This paper presents a case study of the design and optimization of a hybrid AL system to improve heavy-oil production. We systematically design and model a hybrid electrical-submersible-pump/gas-lift (ESP/GL) system to enhance wellbore lifting and production optimization. We found that the implementation of hybrid ESP/GL system provides the flexibility to boost production and reduces production downtime. Results from the pilot test show that the production rate in hybrid mode is approximately 30% higher than in ESP-only mode. The power consumption of the hybrid mode is 3% lower in the ESP-only mode. Furthermore, the average ESP service life exceeds six years which is better than expected in the field development plan. The pump-performance-curve model is built with corrections for density and viscosity owing to the increased water production. We observed a higher pressure drawdown with GL injection at fixed ESP frequency. The GL injection reduces the density of the fluid column above the ESP, resulting in less pressure loss across the pump, less power consumption, and potentially extended service life. The nodal-analysis results suggest that the pump capacity can be considerably expanded by manipulating the GL rate instead of increasing the frequency.

Subsea Oil and Gas Production Assurance Using Artificial Lifts and Nodal Analysis

2015 ◽  
Author(s):  
Ikenna A. Okaro ◽  
Longbin Tao
Keyword(s):  
System Analysis ◽  
Oil And Gas ◽  
Oil Production ◽  
Gas Production ◽  
Submersible Pump ◽  
Oil And Gas Production ◽  
Nodal Analysis ◽  
Multiphase Pump ◽  
Electrical Submersible Pump ◽  
The Impact

This paper describes how the operation of deep, subsea oil wells can be analyzed and optimized using artificial lift systems. A modest explanation was offered about an enhanced Hubbert model for determining production targets at pre-feed phase of project. In addition, the impact of artificial lifts on the economics of subsea wells facing hyperbolic production decline was illustrated. The principle of Nodal analysis was highlighted and applied to optimize a proposed subsea oil production case. Configurations of a nominally rated rod pump, a multiphase pump and an electrical submersible pump were modelled in a steady-state flow using Pipesim software and the simulated results which were functions of liquid flow rate and pressure distribution across the production system exposed the behavior of the system. The results showed that over 100% volumetric efficiency was achieved using a combination of electrical submersible pump at the bottom hole and a multiphase pump at riser base. A guide is presented on how to predict, analyze and enhance the recovery curve of subsea oil production using artificial lifts and nodal-system analysis. The benefit of this work is an enabling cost-effective approach for ensuring production assurance in deep water oil and gas production.

Flow Transients in Wells After Startup of Electrical Submersible Pump

2003 ◽  
Author(s):  
Yuri V. Fairuzov ◽  
Oscar Ruiz-Maldonado ◽  
Jose Gonzalez-Guevara ◽  
Augustin Galindo
Keyword(s):  
Production System ◽  
Field Data ◽  
Transient Flow ◽  
System Model ◽  
System Response ◽  
Submersible Pump ◽  
Iterative Coupling ◽  
Model Predictions ◽  
Fluid Transients ◽  
Electrical Submersible Pump

Fluid transients in the production system caused by startup of electrical submersible pump (ESP) were studied in the present paper. A numerical model of an ESP well was developed. The system model consists of three modules. The first module, the well model, predicts transient flow in the tubing and the casing. The second module describes the ESP performance characteristics. The third module is a model of single-phase flow in the reservoir. The modules developed are integrated into the whole production system model using an iterative coupling algorithm. The model predictions are compared with field data. The study revealed that the system response on the ESP startup is controlled by dynamic interaction between the well and the reservoir. Model predictions are found to agree qualitatively with field data.

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>

Test and application of electrical submersible pump units at White Tiger field

2019 ◽  
Vol 10 ◽  
pp. 82-86
Author(s):  
A.N. Ivanov ◽  
◽  
V.A. Bondarenko ◽  
M.M. Veliev ◽  
E.V. Kudin ◽  
...  
Keyword(s):  
Submersible Pump ◽  
Electrical Submersible Pump ◽  
White Tiger

Smoothing and expansion of the experimental mode shapes of an electrical submersible pump

2021 ◽  
Vol 229 ◽  
pp. 108975
Author(s):  
R.H.R. Gutiérrez ◽  
U.A. Monteiro ◽  
C.O. Mendonça
Keyword(s):  
Mode Shapes ◽  
Submersible Pump ◽  
Electrical Submersible Pump

SAGD ESP Intake Design Improvement

2021 ◽  
Author(s):  
Frank Zhong ◽  
Patrick Keough ◽  
Kjellb Martel ◽  
Richard Delaloye ◽  
Curtis Goulet ◽  
...  
Keyword(s):  
Pressure Loss ◽  
Produced Water ◽  
Flow Paths ◽  
Severe Motor ◽  
Working Together ◽  
Electrical Submersible Pump ◽  
Motor Load ◽  
Improved Design ◽  
The Right ◽  
Intake Flow

Abstract One of the major challenges in SAGD Electrical Submersible Pump (ESP) operation is produced water flashing to steam when flowing pressure loss is significant, such as at an ESP intake. "Bottom Feeder" style intakes are a standard SAGD ESP intake which has been applied in the SAGD industry for over a decade. However,it was identified in recent years at ConocoPhillips's (CPC) Surmont Oilsands operations that Bottom Feeder intakes can lead to steam flashing in pump at the right conditions. The flashed steam causes significant cavitation in pump, which in turn causes severe motor load chattering. Further to that, steam locking in the pump can occur, which is called a "no flow event" (NFE) in the SAGD industry. ConocoPhillips and Baker Hughes have been working together to optimize SAGD ESPs by utilizing an integral intake to minimize the pressure loss across the intake ports. This would also streamline the connection between intake and pump housing to minimize pressure loss at these intake flow paths. The improved design has been tested in Surmont successfully, and the integral intake has become an optional intake to be applied in the well cases where steam flashing has been known to cause operation interruptions or ESP damages. This paper will review the process undertaken by CPC and Baker Hughes to study the ESP performance with the bottom feeder intake in comparison to the ESP performance with an integral intake.Design and field data will be presented and reviewed to highlight the performance of each system.

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