Integrated Well Completion Strategies with CHOPS to Enhance Heavy Oil Production: A Case Study in Fula Oil Field

2005 ◽  
Author(s):  
Xugang Wang ◽  
Honglan Zou ◽  
Guocheng Li ◽  
Changmou Nie ◽  
Jianbin Chen
Keyword(s):  
Heavy Oil ◽  
Oil Production ◽  
Oil Field ◽  
Well Completion

World First All-Electric Intelligent Completion System with Permanent Monitoring to Evaluate Injection Performance in a Mature Injector Well

2021 ◽  
Author(s):  
Walter Sanchez ◽  
Iván Coronel ◽  
Edgar Mora ◽  
Carlos Giosa ◽  
Monica Satizabal ◽  
...  
Keyword(s):  
Real Time ◽  
Heavy Oil ◽  
Fiber Optic ◽  
Oil Production ◽  
Oil Field ◽  
Technology Selection ◽  
Time Data ◽  
Well Completion ◽  
Operational Costs ◽  
Real Time Data

Abstract Traditional waterflooding methods in heavy oil fields can lead to several problems including reductions of swapping efficiency, channeling of injected water, and low values of recovery factor. These problems are often made worse by other critical factors such as lack of real-time data, operational incidents during injection profile calibration, and complexity of interventions in the existing wells. An innovative solution was implemented in a four-zone injector well in a heavy oil field in Colombia consisting of four intelligent electric valves controlled remotely and distributed fiber optic monitoring to calculate injected flow per zone in real-time. This system allowed the operator to increase oil production in the associated producer wells and eliminate rig-less interventions. The first installation of an All-Electric intelligent completion with distributed fiber optic monitoring was successfully deployed in a complex existing injector well without HSE incidents nor deviations in time and cost. After one year of operation, the system increased production in corresponding producer wells by 62% and saved 30% of operational costs. Additionally, the completion design has improved the injection performance which means that the system requires less injected water to produce the same amount of oil. All these results were possible thanks to the use of a more efficient injection completion and the use of real-time data to make on-time decisions. The importance of this implementation is that it demonstrated that this type of technology not only solves different challenges of the Enhanced Oil Recovery (EOR) strategies of mature fields but also brings additional value in terms of oil production, injection performance, and reduction in operational costs. In this way, this application showed that an intelligent completion - usually expensive in terms of initial investment - is financially viable to implement in mature existing wells with limited CAPEX availability. This paper will present the implementation of an intelligent well completion system that uses permanent distributed fiber optics to monitor water injection in 4 independent zones. The document will also include details regarding the reasons to install this technology in a mature field, well and technology selection, intelligent completion design, and installation. Results will be compared to conventional completion for injector wells that depends on rig-less intervention to measure and regulate injected flow per zone.

New Technology for Flow Assurance in an Extra Heavy Oil Field: Case Study in the Akacias Field

2014 ◽  
Author(s):  
Andres Javier Chaustre Ruiz ◽  
John Jairo Ibagon ◽  
Elkin Alberto Leon Ramirez
Keyword(s):  
Heavy Oil ◽  
New Technology ◽  
Oil Field ◽  
Flow Assurance ◽  
Field Case

scholarly journals A fishtail well design for cyclic steam injection—A case study from Yarega heavy oil field in Russia

2019 ◽  
Vol 7 (6) ◽  
pp. 2437-2455 ◽  
Author(s):  
German A. Abzaletdinov ◽  
Temitope Ajayi ◽  
Youssuf A. Elnoamany ◽  
Sergey Durkin ◽  
Ipsita Gupta
Keyword(s):  
Heavy Oil ◽  
Steam Injection ◽  
Oil Field ◽  
Well Design

Unlocking the Potential of a Mature Heavy Oil Field Using Innovative Well Placement Technology: A Case Study from Offshore China

2014 ◽  
Author(s):  
Chao Min Nie ◽  
Yong Jia ◽  
Yong Hu ◽  
Xuwei Bie ◽  
Liuhe Yang ◽  
...  
Keyword(s):  
Heavy Oil ◽  
Oil Field ◽  
Well Placement

Electromagnetic Heating for Heavy Oil Production: Case Study of a Field Applicability (Russian)

2015 ◽  
Author(s):  
M. Rafiee ◽  
A. Behr ◽  
E. Lessner ◽  
D. Diehl ◽  
B. Trautmann ◽  
...  
Keyword(s):  
Heavy Oil ◽  
Oil Production ◽  
Electromagnetic Heating

Expansion of Data Analytics for Optimizing Steamflood In Mukhaizna Heavy Oil Field

2021 ◽  
Author(s):  
Mohammed Al Asimi ◽  
Nasar Al Qasabi ◽  
Duc Le ◽  
Yuchen Zhang ◽  
Di Zhu ◽  
...  
Keyword(s):  
Heavy Oil ◽  
Data Analytics ◽  
Oil Production ◽  
Steam Injection ◽  
Lessons Learned ◽  
Oil Field ◽  
Production Performance ◽  
Optimization Process ◽  
Successful Implementation ◽  
Full Field

Abstract After successful implementation of data analytics for steamflood optimization at the Mukhaizna heavy oil field in Oman late 2018, Occidental expanded the project to two additional areas with a total of 626 wells in 2019, followed by full field coverage of more than 3,200 wells in 2020. In 2019, two separate low-fidelity proxy models were built to model the two pilot areas. The models were updated with more features to account for additional reservoir phenomena and a larger scope. On the proxy engine side, speed and robustness were improved, resulting in reduced CPU processing time and lower cost. Because of advancements in software programing and the pilots’ encouraging production performance, full-field coverage was accelerated so the model could support the efforts in optimizing steam injection during the 2020 OPEC+ production cut, not only to comply with allotted quotas, but also to allocate the resources optimally, especially the costly steam. Good improvements have been observed in overall steamflood performance, the models’ capabilities, and the optimization workflow. The steam/oil ratio has been reduced through the increase in oil production in both expanded study areas while keeping the total steam injection volume constant. Overall field steam utilization was improved both during the 2020 OPEC+ production cuts and during the production ramp-up stage afterward. With the continuous improvement in supporting tools and scripts, most of the steam optimization process steps were automated, from preparing, checking, and formatting input data to analyzing, validating, and visualizing the model outputs. Another result of these improvements was the development of a user-friendly web application to manage the model workflow efficiently. This web app greatly improved the process of case submittals, including data preparation and QC, running models (history matching and forecasting), as well as visualization of the entire workflow. In terms of optimization workflow, these improvements resulted in less time spent by the field optimization engineer in updating, refreshing, and generating new model recommendations. It also helped reduce the time spent by the reservoir management team (RMT) to test and validate the new ideas before field implementation. This paper will describe the improvements in the proxy model and the overall optimization process, show the observed oil production increases, and discuss the challenges faced and the lessons learned.

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