Innovative Gas Lift in Heavy Oil Wells: Case Study in Block 6, Sudan

2013 ◽  
Author(s):  
Tang Xueqing ◽  
Li Guocheng ◽  
Fahmi Abdalla Alawad ◽  
Yu Keqiang ◽  
Cai Bo ◽  
...  
Keyword(s):  
Heavy Oil ◽  
Oil Wells ◽  
Gas Lift

scholarly journals A new experimental method to prevent paraffin - wax formation on the crude oil wells: A field case study in Libya

2015 ◽  
Vol 69 (3) ◽  
pp. 269-274 ◽  
Author(s):  
Elnori Elhaddad ◽  
Alireza Bahadori ◽  
Manar Abdel-Raouf ◽  
Salaheldin Elkatatny
Keyword(s):  
Pour Point ◽  
Oil Wells ◽  
Fluid Temperature ◽  
Gas Field ◽  
Ethylene Copolymers ◽  
Comb Polymers ◽  
Point Temperature ◽  
Temperature Range ◽  
Gas Lift

Wax formation and deposition is one of the most common problems in oil producing wells. This problem occurs as a result of the reduction of the produced fluid temperature below the wax appearance temperature (range between 46?C and 50?C) and the pour point temperature (range between 42?C and 44?C). In this study, two new methods for preventing wax formation were implemented on three oil wells in Libya, where the surface temperature is, normally, 29?C. In the first method, the gas was injected at a pressure of 83.3 bar and a temperature of 65?C (greater than the pour point temperature) during the gas-lift operation. In the second method, wax inhibitors (Trichloroethylene-xylene (TEX), Ethylene copolymers, and Comb polymers) were injected down the casings together with the gas. Field observations confirmed that by applying these techniques, the production string was kept clean and no wax was formed. The obtained results show that the wax formation could be prevented by both methods.

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.

Preventing Proppant and Formation-Sand Production in High Water Cut, Heavy-Oil Wells: A Field Study from Argentina

2009 ◽  
Author(s):  
Daniel Daparo ◽  
Luis Soliz ◽  
Eduardo Roberto Perez ◽  
Carlos Iver Vidal Saravia ◽  
Philip Duke Nguyen ◽  
...  
Keyword(s):  
Field Study ◽  
Heavy Oil ◽  
High Water ◽  
Oil Wells ◽  
Sand Production ◽  
High Water Cut ◽  
Water Cut

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

Rich-Gas Condensate Huff and Puff Process in High-Volume, Watered-Out, and Highly Viscous Heavy Oil Wells, Case Study in Iraq

2021 ◽  
Author(s):  
Xueqing Tang ◽  
Ruifeng Wang ◽  
Zhongliang Cheng ◽  
Hui Lu
Keyword(s):  
High Pressure ◽  
Heavy Oil ◽  
Oil Quality ◽  
Oil Wells ◽  
Gas Condensate ◽  
Oil Viscosity ◽  
Foamy Oil ◽  
Artificial Lift ◽  
Water Coning ◽  
The Dead

Abstract Halfaya field in Iraq contains multiple vertically stacked oil and gas accumulations. The major oil horizons at depth of over 10,000 ft are under primary development. The main technical challenges include downdip heavy oil wells (as low as 14.56 °API) became watered-out and ceased flow due to depleted formation pressure. Heavy crude, with surface viscosities of above 10,000 cp, was too viscous to lift inefficiently. The operator applied high-pressure rich-gas/condensate to re-pressurize the dead wells and resumed production. The technical highlights are below: Laboratory studies confirmed that after condensate (45-52ºAPI) mixed with heavy oil, blended oil viscosity can cut by up to 90%; foamy oil formed to ease its flow to the surface during huff-n-puff process.In-situ gas/condensate injection and gas/condensate-lift can be applied in oil wells penetrating both upper high-pressure rich-gas/condensate zones and lower oil zones. High-pressure gas/condensate injected the oil zone, soaked, and then oil flowed from the annulus to allow large-volume well stream flow with minimal pressure drop. Gas/condensate from upper zones can lift the well stream, without additional artificial lift installation.Injection pressure and gas/condensate rate were optimized through optimal perforation interval and shot density to develop more condensate, e.g. initial condensate rate of 1,000 BOPD, for dilution of heavy oil.For multilateral wells, with several drain holes placed toward the bottom of producing interval, operating under gravity drainage or water coning, if longer injection and soaking process (e.g., 2 to 4 weeks), is adopted to broaden the diluted zone in heavy oil horizon, then additional recovery under better gravity-stabilized vertical (downward) drive and limited water coning can be achieved. Field data illustrate that this process can revive the dead wells, well production achieved approximately 3,000 BOPD under flowing wellhead pressure of 800 to 900 psig, with oil gain of over 3-fold compared with previous oil rate; water cut reduction from 30% to zero; better blended oil quality handled to medium crude; and saving artificial-lift cost. This process may be widely applied in the similar hydrocarbon reservoirs as a cost-effective technology in Middle East.

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