Using an FPGA-based fault injection technique to evaluate software robustness under SEEs: A case study

2011 ◽  
Author(s):  
M. Portela-Garcia ◽  
A. Lindoso ◽  
L. Entrena ◽  
M. Garcia-Valderas ◽  
C. Lopez-Ongil ◽  
...  
Keyword(s):  
Fault Injection ◽  
Injection Technique ◽  
Software Robustness

Lessons learned in establishing a quality improvement project to reduce hospital acquired infections in the neonatology ward at a referral hospital in Rwanda

2016 ◽  
Vol 24 (4) ◽  
pp. 341-348 ◽  
Author(s):  
Naasson Gafirimbi ◽  
Rex Wong ◽  
Eva Adomako ◽  
Jeanne Kagwiza
Keyword(s):  
Quality Improvement ◽  
Lessons Learned ◽  
Referral Hospital ◽  
Quality Improvement Project ◽  
Injection Technique ◽  
Improve Quality ◽  
Improvement Project ◽  
Content Type ◽  
Hospital Acquired

Purpose Improving healthcare quality has become a worldwide effort. Strategic problem solving (SPS) is one approach to improve quality in healthcare settings. This case study aims to illustrate the process of applying the SPS approach in implementing a quality improvement project in a referral hospital. Design/methodology/approach A project team was formed to reduce the hospital-acquired infection (HAI) rate in the neonatology unit. A new injection policy was implemented according to the root cause identified. Findings The HAI rate decreased from 6.4 per cent pre-intervention to 4.2 per cent post-intervention. The compliance of performing the aseptic injection technique significantly improved by 60 per cent. Practical implications This case study illustrated the detailed application of the SPS approach in establishing a quality improvement project to address HAI and injection technique compliance, cost-effectively. Other departments or hospitals can apply the same approach to improve quality of care. Originality/value This study helps inform other hospitals in similar settings, the steps to create a quality improvement project using the SPS approach.

Smart Segmented Polymer Injection Pilot: A Case Study

2021 ◽  
Author(s):  
Fuchao Sun ◽  
Xiaohan Pei ◽  
Xubo Gai ◽  
Shuang Sun ◽  
Shifeng Hu
Keyword(s):  
Real Time ◽  
Pressure Sensors ◽  
Adjustment Process ◽  
Injection Technique ◽  
Control Line ◽  
Real Time Monitoring ◽  
Time Data ◽  
Polymer Injection ◽  
Polymer Flood

Abstract Polymer flood is proved an effective method for EOR in China. Traditional segmented polymer injection technique cannot obtain continuous layer parameters. Real-time monitoring is necessary for polymer flood because downhole pressure and flowrate vary more often than waterflood. Existing technique for layered monitoring and flowrate adjustment is wireline test. There is no smart technique which can realize real-time monitoring and automatic flowrate control. In this paper, a smart segmented injection technique for polymer flood well is introduced. A smart distributor is permanently placed in each layer. It is composed of flowmeter, temperature sensor, two pressure sensors, downhole choke and electrical control unit. The special flowmeter is adopted for polymer flowrate test. All the distributors are connected together by a single control line which is set outside of the tubing string. Operator can read the data of each layer and adjust the flowrate whenever needed at any time which makes the technique a smart one. The smart technique for polymer flood wells has been implemented in a polymer well in Daqing oilfield of China. A case study for smart segmented polymer injection pilot is introduced in detail including technical principle, indoor test results, construction process and adjustment process. The application results show that the operator on the ground can easily obtain downhole tubing pressure, layer annulus pressure, temperature and flowrate on line. The sample time can be set to any one between 1-65536s according to geological engineer's advice. There is no limitation caused by battery power because the distributor is powered by cable on the ground. In terms of adjustment, the flowrate can be adjusted according to the target value. And it can also be regulated at any time manually, just needing pushing the mouse in the office. The application also displays that the smart segmented technique has the advantage for polymer injection because of larger change of layered parameters. It can provide more real-time data for oil development engineer and the data are beneficial for better understanding and optimization of the reservoir. Therefore, the smart segmented polymer injection has a great potential for EOR based on polymer flood.

Application of Supercritical Water Coupled with Toe-Point Injection Technique for Heavy Oil EOR: A Case Study

2018 ◽  
Author(s):  
Shiyuan Qu ◽  
Hanqiao Jiang ◽  
Junjian Li ◽  
Jinchuan Hu ◽  
Fengrui Sun ◽  
...  
Keyword(s):  
Supercritical Water ◽  
Heavy Oil ◽  
Injection Technique ◽  
Point Injection

scholarly journals Performance of free gases during the recovery enhancement of shale gas by CO2 injection: a case study on the depleted Wufeng–Longmaxi shale in northeastern Sichuan Basin, China

2020 ◽  
Author(s):  
Jun Liu ◽  
Ling-Zhi Xie ◽  
Bo He ◽  
Peng Zhao ◽  
Huai-Yu Ding
Keyword(s):  
Coupling Model ◽  
Co2 Injection ◽  
Injection Technique ◽  
Production Well ◽  
Reservoir Properties ◽  
Northeastern Sichuan ◽  
Longmaxi Shale ◽  
The Matrix ◽  
Free Gases

AbstractIn this work, a novel thermal–hydraulic–mechanical (THM) coupling model is developed, where the real geological parameters of the reservoir properties are embedded. Accordingly, nine schemes of CO2 injection well (IW) and CH4 production well (PW) are established, aiming to explore the behavior of free gases after CO2 is injected into the depleted Wufeng–Longmaxi shale. The results indicate the free CH4 or CO2 content in the shale fractures/matrix is invariably heterogeneous. The CO2 involvement facilitates the ratio of free CH4/CO2 in the matrix to that in the fractures declines and tends to be stable with time. Different combinations of IW–PWs induce a difference in the ratio of the free CH4 to the free CO2, in the ratio of the free CH4/CO2 in the matrix to that in the fractures, in the content of the recovered free CH4, and in the content of the trapped free CO2. Basically, when the IW locates at the bottom Wufeng–Longmaxi shale, a farther IW–PWs distance allows more CO2 in the free phase to be trapped; furthermore, no matter where the IW is, a shorter IW–PWs distance benefits by getting more CH4 in the free phase recovered from the depleted Wufeng–Longmaxi shale. Hopefully, this work is helpful in gaining knowledge about the shale-based CO2 injection technique.

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