Service Industry & University Collaboration in Teaching Production Optimization with Artificial Lift

2014 ◽  
Author(s):  
Rajan N Chokshi ◽  
William C Lane ◽  
Shari Dunn-Norman ◽  
Chatetha Chumkratoke
Keyword(s):  
Service Industry ◽  
Production Optimization ◽  
Artificial Lift

First Digital Intelligent Artificial Lift Production Optimization Technology in UAE Dual-String Gas Lift Well - Business Case and Implementation Plan

2019 ◽  
Author(s):  
Ahmed Alshmakhy ◽  
Khadija Al Daghar ◽  
Sameer Punnapala ◽  
Shamma AlShehhi ◽  
Abdel Ben Amara ◽  
...  
Keyword(s):  
Business Case ◽  
Production Optimization ◽  
Implementation Plan ◽  
Artificial Lift ◽  
Gas Lift

Production Optimization over 20% with Artificial Lift ESP Pilot Systems in Mature Oil Field, Case Study from Middle East

2014 ◽  
Author(s):  
Hector Aguilar ◽  
Aref Almarzooqi ◽  
Tarek Mohamed El Sonbaty ◽  
Leigber Villarreal
Keyword(s):  
Middle East ◽  
Production Optimization ◽  
Oil Field ◽  
Field Case ◽  
Artificial Lift

scholarly journals Significant production improvement using optimization of completion and artificial lift: case studies from South-West Iran

2020 ◽  
Author(s):  
Rahman Ashena ◽  
Mahmood Bataee ◽  
Hamed Jafarpour ◽  
Hamid Abbasi ◽  
Anatoly Zolotukhin ◽  
...  
Keyword(s):  
Case Studies ◽  
Gas Injection ◽  
Field Tests ◽  
Production Optimization ◽  
South West ◽  
Artificial Lift ◽  
Production Improvement ◽  
Artificial Gas Lift ◽  
Gas Lift ◽  
Standard Gas

AbstractProductivity of wells in South-West Iran has decreased due to completion and production problems in recent decades. This is a large risk against sustainable production from the fields. To allow stable production, an important measure is completion and production optimization including artificial lift methods. This was investigated using simulations validated by pilot field tests. Several case studies were considered in terms of their completion and production. Five scenarios were investigated: natural production through annulus and tubing (scenario-1 and 2), artificial gas lift production through annulus (scenario-3), through tubing using non-standard gas lift (scenario-4) and using standard gas lift (scenario-5). Scenario-1 is currently the case in most wells of the field. To find the optimal scenario and completion/production parameters, simulations of 11 wells of an oilfield in the region were carried out using nodal and sensitivity analysis. The optimized parameters include wellhead pressures (WHPs), tubing dimensions, maximum tolerable water cuts and gas oil ratios and artificial gas injection rate. Simulation results were validated by pilot field tests. In addition, appropriately selected wellhead and Christmas trees for all scenarios were depicted. Simulations confirmed by field pilot tests showed that optimization of completion and production mode and parameters can contribute largely to production improvement. The results showed that the current scenario-1 is the worst of all. However, production through tubing (scenario-2) is optimal for wells which can produce with natural reservoir pressure, with an increase of 800 STB/Day rate per well compared with scenario-1. However, for wells requiring artificial gas lift, the average production rate increase (per well) from the annulus to tubing production was 1185 STB/Day. Next, using the standard gas lift (scenario-5) was found to be the optimal mode of gas lifting and is strongly recommended. WHPs in scenario-5 were the greatest of all, whereas scenario-1 gave the lowest WHPs. The optimal tubing diameter and length were determined. The greatest maximum tolerable water cut was obtained using scenario-5, whereas the lowest was with scenario-1. The maximum tolerable GOR was around 1900 scf/STB. Changing of scenarios did not have significant effect on maximum tolerable GOR. The optimal artificial gas injection rates were found. This validated simulation work proved that completion and production optimization of mode and parameters had considerable contribution to production improvement in South-West Iran. This sequential comprehensive work can be applied in any other field or region.

Well Performance and Production Optimization Through the Use of ESPs as Artificial Lift Method

2015 ◽  
Author(s):  
Guilherme Hartenbach ◽  
João Magalhães ◽  
Yngve Belsvik ◽  
Rui Pessoa ◽  
Daniel Lemos
Keyword(s):  
Production Optimization ◽  
Well Performance ◽  
Artificial Lift

scholarly journals Production optimization of a network of multiple wells with each well using a combination of Electrical Submersible Pump and Gas lift

2021 ◽  
Author(s):  
Son Tung Pham ◽  
Dinh Hau Tran
Keyword(s):  
Energy Saving ◽  
Production Rate ◽  
Small Diameter ◽  
Production Optimization ◽  
Optimization Process ◽  
Binary Search Tree ◽  
Optimum Operating ◽  
Total Production ◽  
Artificial Lift ◽  
Gas Lift

AbstractArtificial lift methods such as ESP and GL are commonly used in oil wells around the world, especially in offshore wells. However, these two methods are normally used separately, and this paper therefore aimed to study the possible combination of ESP and GL by analyzing its effects on energy saving using equivalent depth method and on production rate as well as on ESP life cycle using nodal analysis. The paper also performed the production optimization for a network of wells using each well a combination of GL and ESP. The optimization process consists of selecting the appropriate operation frequency for the ESP system and the injection gas lift distributed to each well with the aim of maximizing the total production of the network. In addition, this optimization process was conducted in two cases: unlimited and limited volume of injection gas lift. In case the GL flow is limited, the BST (Binary Search Tree) algorithm was used to determine the suitable gas rates injected into each well to maximize the total network production. The optimization workflow proposed in this study was applied to the field X in Cuu Long basin of Vietnam and was calibrated from the real data of this field. The results demonstrated the advantage of the combination of ESP and GL in energy saving and in application for small diameter wells. In addition, the workflow and source code will allow engineers to replicate the results and to apply this method for future studies in order to determine optimum operating parameters of this hybrid artificial lift to achieve the highest production rate from a network of multiple wells.

scholarly journals The Critical Investigation on Essential Parameters to Optimize the Gas Lift Performance In “J” Field Using Prosper Modelling

2018 ◽  
Vol 7 (2) ◽  
pp. 46-54
Author(s):  
Fitrianti Fitrianti ◽  
Dike Fitriansyah Putra ◽  
Desma Cendra
Keyword(s):  
Well Being ◽  
Production Optimization ◽  
Productivity Index ◽  
Injection System ◽  
Driving Mechanism ◽  
Well Performance ◽  
Artificial Lift ◽  
Index Value ◽  
Gas Lift ◽  
Selection Of

The declining reservoir, oil production and pressure depletion with the well being produced, the results of the investment of the well will also decrease. For that there needs to be energy that can help to lift the fluid to the surface. One of the artificial lift methods that can be used is a gas lift. Gas lift is a method commonly used when there is a natural gas source as an injection gas supply. The selection of the artificial lift method is based on several considerations, namely the reservoir conditions, fluid conditions, well conditions, conditions on the surface, availability of electricity, availability of gas, and sand problem. The influential parameters in the selection of gas lifts include: Productivity Index (PI), Gas Liquid Ratio (GLR), depth of the well and driving mechanism from the reservoir. The Gas Lift that the production optimization wants to do is the injection system in a Continuous Gas Lift. Used in wells that have a high Productifity Index value. Where in the LB field to be analyzed, the Productifity Index value is 2.0 bpd / psi. This study intends to optimize a gaslift well performance as an effort to maximize the results of well production. Based on the research that has been done using Prosper Modeling on the “J” field, the following conclusions are obtained the effect of pressure and viscosity on the gas lift well flow rate in this condition can be said to be efficient, because the conditions / pressure given at temperatures below 300 F can reach the miscible condition and from the results of determining the optimal conditions to get the best well performance, obtain an optimal liquid rate of 1829.4 STB / D with an oil rate of 36.6 STB / D.   Keywords: Gas lift, Optimization, Immiscible Pressure, Viscosity

Digital Intelligent Artificial Lift DIAL Gas Lift Production Optimization Deployments Across Assets

2021 ◽  
Author(s):  
Ahmed Alshmakhy ◽  
Yann Bigno ◽  
Talha Saqib ◽  
Moazim Soomro ◽  
Juan Faustinelli ◽  
...  
Keyword(s):  
Injection Rate ◽  
American Petroleum Institute ◽  
Production Optimization ◽  
Flow Area ◽  
Well Production ◽  
Surface Control ◽  
Artificial Lift ◽  
Technical Details ◽  
Gas Lift

Abstract Abu Dhabi National Oil Company (ADNOC) is expanding the use of DIAL (Digital Intelligent Artificial Lift) technology, across its assets, through a range of different oil production applications. These include gas lifted single and dual completions, Extended Reach Drilling (ERD) wells and In-Situ gas lift. DIAL is a first-of-kind technology that enhances the efficiency of gas lift through downhole data, surface control and digital operations. This data driven approach enables production automation and minimizes well intervention requirements. This paper will present four different applications for the technology. These applications were selected by ADNOC assets, as they were deemed to bring the most value for DIAL implementation. The paper will describe technical details for each application, including gas lift designs, completion specificities, installation procedures and benefits observed or anticipated. A summary of the value add for each of the four applications are listed below. Gas lifted single completion is the most common application for the DIAL system. The benefits of the application have been described in previous papers and range from intervention savings to production optimization. This paper will highlight the additional benefit of automation, making full use of the system digital features. Gas lifted dual string completion, where the technology enables efficient lift of both strings, improving well production in the range of 40 to 100%. API (American Petroleum Institute) does not recommend pressure operated gas lift in dual wells. DIAL offers stability, simultaneous lifting of both strings through surface control and downhole data. ERD gas lifted well required flexibility for its gas lift operations. DIAL enables real time changes of injection depths based on reservoir response, and units can be installed deeper into the deviated section of the well without any deviation limits. In-Situ gas lift is a specific application where a gas zone is used to lift production from the oil zone in the same well. DIAL enables measurement of the gas injection rate at the point of injection, and adjustment of the flow area to optimize production. This is a world's first use of the technology for this type of application. A range of applications are described in this paper with many technical details, recommendations and lessons learnt to enable replication within the industry. Some of these applications are world first.

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