The Application of Gas-Lift Injection Pressure-Operated Spring Valves in the Western Operated Area of the Prudhoe Bay Field: A Case Study

1993 ◽  
Author(s):  
G.R. Vigil ◽  
G.S. Nordlander ◽  
R.L. Valencia ◽  
J.O. Watkins
Keyword(s):  
Injection Pressure ◽  
Prudhoe Bay ◽  
Gas Lift

Gas Lift Design Optimization Using Intelligent Gas Lift Valves a KJO Case Study

2021 ◽  
Author(s):  
Abdullah Al Qahtani ◽  
Sultan Al-Aklubi ◽  
Abdel BenAmara ◽  
Stephen Faux
Keyword(s):  
Production Rate ◽  
Oil And Gas ◽  
Injection Pressure ◽  
Oil Wells ◽  
Oil Field ◽  
Added Value ◽  
Well Performance ◽  
Time Data ◽  
Gas Lift

Abstract Gas lift is becoming a big consideration in most of oil field as an economic, sustainable means of artificially lifting weak/dead oil wells. This is especially considered in high volume wells. Gas lift is employed, by injecting gas into the well tubing through gas lift valves, to reduce the hydrostatic pressure of the produced fluid column in oil wells, leading to a lower flowing bottom-hole pressure. The increased pressure differential induced across the sand face from the in situ reservoir pressure, assists in lifting the produced fluid to the surface. Optimizing the level of injected gas is important in maximizing the production, and hence the financial performance of the well. The challenge for most oil and gas producers is that they do not effectively maximize production with the most efficient use of gas lift resources. The challenge is that there is a lack of accurate and timely production data from the well tests. The optimal inject rate for a well is based on a ratio of injected gas rate to the liquid production rate. Under injecting the gas decreases the well production rate. The objective of optimization in gas-lifted wells is to achieve optimal production rate with minimal gas injection volume to spare gas for other wells, when the compression capacity is limited. Optimally allocated injection gas helps reduce unnecessary strain on your facility and maximize performance, this in turn enhances the life of production assets significantly. This paper presents a case study from Khafji Joint Operation fields, utilizing the intelligent digital gas lift valve to optimize the design and performance of the gas lift wells. The case study demonstrates the value proposition by using the digital intelligent gas lift system to maximize well performance whilst reducing injected gas, in addition to acquired real-time data that help assess the process. That optimization was achieved on well level by optimizing the well parameters such as point of injection, injection rate, and injection pressure. All these aspects have been investigated and presented in this study by using field data and flow simulations. Results showed the potential added value of the system.

Real-Time Diagnostics of Gas Lift Systems: A Case Study

2010 ◽  
Vol 62 (05) ◽  
pp. 55-56
Author(s):  
Dennis Denney
Keyword(s):  
Real Time ◽  
Gas Lift

scholarly journals IMPACT OF GAS LIFT INJECTION RATE ON OIL PRODUCTION RATE

2021 ◽  
pp. 76-94
Author(s):  
Dr. Mohamed A. GH. Abdalsadig
Keyword(s):  
Real Time ◽  
Energy Demand ◽  
Oil And Gas ◽  
Injection Pressure ◽  
Production Operation ◽  
Well Performance ◽  
Time Data ◽  
Daily Work ◽  
Wellhead Pressure ◽  
Gas Lift

As worldwide energy demand continues to grow, oil and gas fields have spent hundreds of billions of dollars to build the substructures of smart fields. Management of smart fields requires integrating knowledge and methods in order to automatically and autonomously handle a great frequency of real-time information streams gathered from those wells. Furthermore, oil businesses movement towards enhancing everyday production skills to meet global energy demands signifies the importance of adapting to the latest smart tools that assist them in running their daily work. A laboratory experiment was carried out to evaluate gas lift wells performance under realistic operations in determining reservoir pressure, production operation point, injection gas pressure, port size, and the influence of injection pressure on well performance. Lab VIEW software was used to determine gas passage through the Smart Gas Lift valve (SGL) for the real-time data gathering. The results showed that the wellhead pressure has a large influence on the gas lift performance and showed that the utilized smart gas lift valve can be used to enhanced gas Lift performance by regulating gas injection from down hole.

Integrated Workflow for Feasibility Study of Cuttings Reinjection Based on 3D Geomechanics Analysis and Case Study

2021 ◽  
Author(s):  
Xinpu Shen
Keyword(s):  
Feasibility Study ◽  
Best Practice ◽  
Injection Pressure ◽  
Accurate Solution ◽  
Fault Reactivation ◽  
Injection Well ◽  
Maximum Magnitude ◽  
Richter Scale ◽  
Effective Stress Ratio

Abstract This paper presents an integrated workflow for feasibility study of cuttings reinjection (CRI) based on 3D geomechanics analysis. Solutions of various mechanical variables obtained with 3D geomechanics analysis at various level of scale are used as basis for designing parameters of CRI. Solutions of geomechanics analysis provide basis for a feasibility study and/or design of CRI: solution of 3D geostress distribution and the effective stress ratio are the essential factors for selecting the best location of injection well; solution of 1D geomechanics analysis provides basis for choice of true vertical depth (TVD) interval for injection sections; and hydraulic fracturing performed in the framework of 3D geomechanics analysis provides the most accurate solution for both the injection pressure window and fault reactivation related to CRI as well as estimation of seismic behavior. Example of feasibility study of cuttings reinjection with the integrated workflow proposed here is presented with data from a case in offshore West Africa. Solutions of geomechanics analysis are used for decision making at various stages of CRI. There are several faults in this region. The location of the injection well is chosen at a place with principal stress ratio's value at 0.68. The interval of injection well section is chosen as a 140-ft section with center at TVD = 6,700 ft. The numerical solution of injection pressure window is defined with 46 MPa as lower bound and 80 MPa as upper bound. The width of the fracture is 0.069 m, and length and height are 4,000 m and 100 m respectively. The accommodation volume of fluid with cuttings is 2.76×104 m3. The maximum magnitude of Richter scale of the seismicity corresponding to the fault reactivation is 3.15. The case study described in this paper provides an integrated workflow for feasibility study of CRI based on 3D geomechanics analysis. A best practice for this type of CRI design is also presented.

Innovations of Gas Lift in Prolific, Long-perforations, and Multilayered Wells, Case Study in Sudan

2016 ◽  
Author(s):  
Xueqing Tang ◽  
Lirong Dou ◽  
Ruifeng Wang ◽  
Jie Wang ◽  
Shengbao Wang ◽  
...  
Keyword(s):  
High Water ◽  
Water Breakthrough ◽  
Start Up ◽  
Production Wells ◽  
Decline Curves ◽  
High Water Cut ◽  
Water Cut ◽  
Gas Lift

ABSTRACT Jake field, discovered in July, 2006, contains 10 oil-producing and 12 condensate gas-producing zones. The wells have high flow capacities, producing from long-perforation interval of 3,911 ft (from 4,531 to 8,442 ft). Production mechanisms include gas injection in downdip wells and traditional gas lift in updip, zonal production wells since the start-up of field in July, 2010. Following pressure depletion of oil and condensate-gas zones and water breakthrough, traditional gas-lift wells became inefficient and dead. Based on nodal analysis of entire pay zones, successful innovations in gas lift have been made since March, 2013. This paper highlights them in the following aspects: Extend end of tubing to the bottom of perforations for commingled production of oil and condensate gas zones, in order to utilize condensate gas producing from the lower zones for in-situ gas lift.Produce well stream from the casing annulus while injecting natural gas into the tubing.High-pressure nitrogen generated in-situ was used to kick off the dead wells, instead of installation of gas lift valves for unloading. After unloading process, the gas from compressors was injected down the tubing and back up the casing annulus.For previous high water-cut producers, prior to continuous gas lift, approximately 3.6 MMcf of nitrogen can be injected and soaked a couple of days for anti-water-coning.Two additional 10-in. flow lines were constructed to minimize the back pressure of surface facilities on wellhead. As a consequence, innovative gas-lift brought dead wells back on production, yielding average sustained liquid rate of 7,500 bbl/d per well. Also, the production decline curves flattened out than before.

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