Achieving Operational Excellence for Gas Lift Modeling in High Angle Wells with Multidisiplinary Approach

2020 ◽  
Author(s):  
F. Sajjad
Keyword(s):  
Flow Instability ◽  
Productivity Index ◽  
Flow Assurance ◽  
Reservoir Pressure ◽  
High Angle ◽  
Daily Production ◽  
Design Modification ◽  
Velocity Changes ◽  
Gas Lift ◽  
Deviated Wells

High angle wells are compulsory in offshore fields. These types of wells require better understanding on flow assurance dynamics and better planning on well intervention to ensure their operational efficiency. It is important to note that several wells have been experiencing severe production decline even though the current reservoir pressure is still high. In order to have a comprehensive understanding on liquid fallback, a transient fluid flow approach has been employed to investigate multiphase flow during gas lift operations. The simulation presents a 3-dimensional, time-based output that can simulate liquid fallback or severe slugging in pipe as a function of pipe diameter, gas lift valve placement, injected gas rate, and reservoir pressure that can address the flow assurance dynamics. The results from this research can be developed as an additional technical consideration before designing a gas lift system in highly deviated wells. Consideration on the placement of gas lift valves are also paramount in these cases, mainly avoiding places with flow instability or regions with sudden velocity changes. Results from the study, combined with well based performance are then compiled as a general guidance for the contractor to design a gas lift system on the basis of reservoir parameters such as Productivity Index, liquid viscosity and density, well deviation and trajectory, and gas supply to ensure operational and design excellence on gas lift design for deviated wells. Transient based simulation improved completion and gas lift design modification in the Lima Field, where higher and stable liquid production from daily production monitoring resulted in less well intervention from these wells.

Numerical Simulation of Gas Lift Optimization Using Artificial Intelligence for a Middle Eastern Oil Field

2021 ◽  
Author(s):  
Mohammed Ahmed Al-Janabi ◽  
Omar F. Al-Fatlawi ◽  
Dhifaf J. Sadiq ◽  
Haider Abdulmuhsin Mahmood ◽  
Mustafa Alaulddin Al-Juboori
Keyword(s):  
Genetic Algorithm ◽  
Sensitivity Analysis ◽  
Middle Eastern ◽  
Optimization Technique ◽  
Injection Rate ◽  
Oil Field ◽  
Oil Fields ◽  
Reservoir Pressure ◽  
Artificial Lift ◽  
Gas Lift

Abstract Artificial lift techniques are a highly effective solution to aid the deterioration of the production especially for mature oil fields, gas lift is one of the oldest and most applied artificial lift methods especially for large oil fields, the gas that is required for injection is quite scarce and expensive resource, optimally allocating the injection rate in each well is a high importance task and not easily applicable. Conventional methods faced some major problems in solving this problem in a network with large number of wells, multi-constrains, multi-objectives, and limited amount of gas. This paper focuses on utilizing the Genetic Algorithm (GA) as a gas lift optimization algorithm to tackle the challenging task of optimally allocating the gas lift injection rate through numerical modeling and simulation studies to maximize the oil production of a Middle Eastern oil field with 20 production wells with limited amount of gas to be injected. The key objective of this study is to assess the performance of the wells of the field after applying gas lift as an artificial lift method and applying the genetic algorithm as an optimization algorithm while comparing the results of the network to the case of artificially lifted wells by utilizing ESP pumps to the network and to have a more accurate view on the practicability of applying the gas lift optimization technique. The comparison is based on different measures and sensitivity studies, reservoir pressure, and water cut sensitivity analysis are applied to allow the assessment of the performance of the wells in the network throughout the life of the field. To have a full and insight view an economic study and comparison was applied in this study to estimate the benefits of applying the gas lift method and the GA optimization technique while comparing the results to the case of the ESP pumps and the case of naturally flowing wells. The gas lift technique proved to have the ability to enhance the production of the oil field and the optimization process showed quite an enhancement in the task of maximizing the oil production rate while using the same amount of gas to be injected in the each well, the sensitivity analysis showed that the gas lift method is comparable to the other artificial lift method and it have an upper hand in handling the reservoir pressure reduction, and economically CAPEX of the gas lift were calculated to be able to assess the time to reach a profitable income by comparing the results of OPEX of gas lift the technique showed a profitable income higher than the cases of naturally flowing wells and the ESP pumps lifted wells. Additionally, the paper illustrated the genetic algorithm (GA) optimization model in a way that allowed it to be followed as a guide for the task of optimizing the gas injection rate for a network with a large number of wells and limited amount of gas to be injected.

Comparative study of the operational properties of deviated and straight gas-lift wells and sensitivity analysis of pressure gradient

2020 ◽  
pp. 108-117
Author(s):  
V.J. Abdullaev ◽  
Keyword(s):  
Pressure Gradient ◽  
Gas Flow ◽  
Dynamic Pressure ◽  
Flow Simulation ◽  
Mathematical Expression ◽  
Flow Properties ◽  
The Difference ◽  
Gas Lift ◽  
Working Agent ◽  
Deviated Wells

The article presents a benchmarking analysis of the complex well body structure effect on the hydraulic parameters of the liquid-gas flow pattern in deviated wells. The difference between the consumption of the working agent (gas) required to lift the same amount of liquid from the same depth in vertical and inclined gas-lift wells is shown. Considering the complexity of the hydrodynamic flow properties in deviated wells, the impossibility of analytical flow simulation, the article provides the problem study using statistical methods and gives its practical solution. The article presents a mathematical expression to determine the dynamic pressure gradient using this method, that is, by group calculation of indicators of gas-lift wells with an deviated body, and its numerical value was found.

Production, Injection and Flow of Petroleum with High Levels of CO2: Operational and Flow Assurance Aspects

2016 ◽  
Vol 830 ◽  
pp. 78-84
Author(s):  
Ivanilto Andreolli ◽  
Luciene de Arruda Bernardo
Keyword(s):  
Gas Phase ◽  
Molar Ratio ◽  
Flow Assurance ◽  
Daily Production ◽  
Treatment And Disposal ◽  
Export System ◽  
Theoretical Analyses ◽  
Concentration Levels ◽  
Operational Aspects

Petroleum production always comes accompanied by some contaminants, including CO2. Recent pre-salt exploration in Brazil indicates significant carbon dioxide (CO2) concentration levels. Whereas in post-salt areas a ratio of 1 to 2% in CO2 concentration was observed, in the pre-salt area this molar ratio increased to 15 to 20% in relation to the gas phase, and were even higher in some cases. Several challenges have emerged in the production, treatment and disposal of oil with such high levels of CO2. The aim of this study is to show the management of CO2 in a pre-salt producing platform whose CO2 content is about 18% molar in the gas phase. The focus is on the operational aspects of daily production, where theoretical analyses are compared with the data observed in the field. Scenarios of production, injection, treatment and export are presented with emphasis on the aspects of flow assurance, the characterization of fluids, the integration of the injection-production-export system, and the dilution of CO2.

scholarly journals ANALISA OPTIMASI GAS LIFT PADA SUMUR RS-1 DI LAPANGAN RS

PETRO ◽  
2019 ◽  
Vol 7 (3) ◽  
pp. 127
Author(s):  
Rachmi Septiani ◽  
Muh Taufiq Fathaddin ◽  
Djoko Sulistyanto
Keyword(s):  
Productivity Index ◽  
Net Income ◽  
Artificial Lift ◽  
Gas Lift

<p>Sumur RS-1 adalah sumur yang tidak mampu lagi untuk memproduksikan fluidanya secara sembur alam, sehingga membutuhkan instalasi <em>artificial lift</em>. Untuk produksi harian, sumur tersebut dibantu oleh <em>artificial lift </em>jenis <em>continuous gas lift</em>. Dengan bantuan <em>gas lift</em>, Sumur RS-1 dapat berproduksi selama beberapa tahun. Produksi tertinggi untuk Sumur RS-1 adalah sebesar 273 BFPD. Sumur RS-1 memiliki 3 <em>gas lift valve </em>dengan titik kedalaman injeksi berada pada kedalaman 2.743 ft. Dalam studi ini dilakukan analisia optimasi penggunaan <em>artificial lift </em>yang sudah terpasang yaitu <em>continuous gas lift</em>. Sumur RS-1 memiliki <em>watercut </em>diatas 50%, oleh karena itu, pembuatan grafik IPR Sumur RS-1 menggunakan <em>composite </em>IPR. Maka didapat nilai <em>productivity index </em>Sumur RS-1 sebesar 0,71. Optimasi Sumur RS-1 ini dilakukan dengan meningkatan laju alir gas injeksinya dari 0,002 mmscfd menjadi 0,2 mmscfd karena menghasilkan <em>net income </em>yang paling tinggi yaitu 1.979 USD/d dengan pertambahan <em>oil rate </em>yang awalnya sebesar 33,9 STB/d menjadi sebesar 65,2 STB/d.</p>

scholarly journals Impact of Hydraulic Fracturing on Productivity of Gas Condensate Wells

2020 ◽  
Vol 8 (6) ◽  
pp. 1202-1208
Keyword(s):  
Hydraulic Fracture ◽  
Gas Condensate ◽  
Dew Point ◽  
Darcy Flow ◽  
Productivity Index ◽  
Reservoir Pressure ◽  
Pressure Drops ◽  
Compositional Simulator ◽  
Point Pressure ◽  
Dew Point Pressure

Having an increase in the discovery of gas reservoirs all over the world, the most common problem related to gas condensate wells while producing below dew point condition is condensate banking. As the bottom hole pressure drops below the dew point, the liquid starts to exist and condensate begins to accumulate. Relative permeability of gas will be reduced as well as the well productivity will start to decline. The effect of applying a hydraulic fracture to gas condensate wells is the main objective of this paper. A compositional simulator is utilized to investigate the physical modifications that could happen to gas and condensate during the production life of an arbitrary well. Performing a good designed hydraulic fracture to a gas condensate well typically enhances the production of such well. This increase depends basically on certain factors such as non-Darcy flow, capillary number and capillary pressure. Non-Darcy flow has a dominant impact on gas and condensate productivity index after performing a hydraulic fracture as the simulator indicates. The enhancement of gas and condensate production can be obtained for gas condensate reservoirs in which the reservoir pressure is above or around the dew point pressure to have a margin for the pressure to decline with time and also eliminate the probability of forming condensate in the reservoir. On the other hand if the reservoir pressure is below the dew point pressure, there will be definitely a condensate in the reservoir and a specific design for the hydraulic fracture is a must to get the required enhancement in the production.

First Successful Proppant Frac in a Water Injection Field Strategy, West Qurna-1, South Iraq

2022 ◽  
Author(s):  
Erfan Mustafa Al lawe ◽  
Adnan Humaidan ◽  
Afolabi Amodu ◽  
Mike Parker ◽  
Oscar Alvarado ◽  
...  
Keyword(s):  
Water Injection ◽  
Injection Rate ◽  
Fracture Model ◽  
Productivity Index ◽  
Base Line ◽  
Reservoir Pressure ◽  
Injection Strategy ◽  
Injection Test ◽  
Step Rate ◽  
Step Down

Abstract Zubair formation in West Qurna field, is one of the largest prolific reservoirs comprising of oil bearing sandstone layers interbedded with shale sequences. An average productivity index of 6 STB/D/psi is observed without any types of stimulation treatment. As the reservoir pressure declines from production, a peripheral water injection strategy was planned in both flanks of the reservoir to enhance the existing wells production deliverability. The peripheral injection program was initiated by drilling several injectors in the west flank. Well A1 was the first injector drilled and its reservoir pressure indicated good communication with the up-dip production wells. An injection test was conducted, revealing an estimated injectivity index of 0.06 STB//D/psi. Candidate well was then re-perforated and stimulated with HF/HCl mud acid, however no significant improvement in injectivity was observed due to the complex reservoir mineralogy and heterogeneity associated to the different targeted layers. An extended high-pressure injection test was performed achieving an injectivity index of 0.29 STB/D/psi at 4500 psi. As this performance was sub-optimal, a proppant fracture was proposed to achieve an optimal injection rate. A reservoir-centric fracture model was built, using the petrophysical and geo-mechanical properties from the Zubair formation, with the objective of optimizing the perforation cluster, fracture placement and injectivity performance. A wellhead isolation tool was utilized as wellhead rating was not able to withstand the fracture model surface pressure; downhole gauges were also installed to provide an accurate analysis of the pressure trends. The job commenced with a brine injection test to determine the base-line injectivity profile. The tubing volume was then displaced with a linear gel to perform a step-rate / step-down test. The analysis of the step-rate test revealed the fracture extension pressure, which was set as the maximum allowable injection pressure when the well is put on continuous injection. The step-down test showed significant near wellbore tortuosity with negligible perforation friction. A fracture fluid calibration test was then performed to validate the integrated model leak-off profile, fracture gradient and young’s modulus; via a coupled pressure fall-off and temperature log analysis. Based on the fluid efficiency, the pad volume was adjusted to achieve a tip screen-out. The job was successfully pumped and tip screen-out was achieved after pumping over ~90% of the planned proppant volume. A 7 days post-frac extended injection test was then conducted, achieving an injection rate of 12.5 KBWD at 1300 psi with an injectivity index of 4.2 STB/D/psi. These results proved that the implementation of a reservoir-centric Proppant Fracture treatment, can drastically improve the water injection strategy and field deliverability performance even in good quality rock formations. This first integrated fracture model and water injection field strategy, represents a building platform for further field development optimization plans in Southern Iraq.

Pushing the Boundaries: Tapping "Hard-to-Reach Oil" by Drilling High-Angle Deviated Wells

2013 ◽  
Author(s):  
Jayanta Bardalaye ◽  
Khalid Huomood Al-Azmi ◽  
Mohammed Saad AL-Azmi ◽  
Dawood Salman Belal ◽  
Anandan Mudavakkat ◽  
...  
Keyword(s):  
High Angle ◽  
Deviated Wells
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