Shuai Li born in 1987, he holds a PhD degree at Research Institute of Petroleum Exploration & Development, PetroChina, majoring in oil and gas engineering. He also holds a bachelorâ€™s degree (2011) and a masterâ€™s degree (2014) at China University of Petroleum (Beijing), both in petroleum engineering. He is also a visiting student at the Pennsylvania State University, USA from year 2017 to year 2018.
Based on contact angle and interfacial tension measurement, this paper concentrated on adding surfactants agent into fracturing fluids to increase oil output after hydraulic fracturing. Cationic, anionic and nonionic surfactants were added into slickwater to perform a serious of one end open (OEO) imbibition experiments at a certain concentration. Scanning electron microscope (SEM) and nuclear magnetic resonance (NMR) method were also applied in the detection before and after the imbibition process. Results demonstrated that core samples changed from oil-wet to intermediate-wet or water-wet after soaked in surfactants, cationic surfactant shows a better performance in changing contact angle while different kinds of surfactants have a similar ability in lowering IFT. In the soaking duration, NMR transverse relaxation time (T2) spectrum showed that oil recovered by counter-current imbibition mainly distributed in intervals of 10-1000 ms while oil remained uncovered mainly distributed in intervals of 0.1-10 ms. T2 spectrum moved towards left side and this indicated that aqueous phase migrate from larger pores to smaller ones. Both laboratory experiments and field applications have indicated that adding surfactants into fracturing fluids can significantly increase oil outputs for tight oil-wet reservoirs. Application of this technology can be a good way to solve low production problems for this type of reservoir.
Xiuyu Wang has completed her PhD at the age of 34 years from University of Wyoming and Postdoctoral Studies from the same university. She is currently an associate professor of Department of Pletroleum Engineering at China University of Petroleum in Beijing
In tight oil reservoir, the flow channel of fluids is tiny and the boundary layer effect is obvious, resulting in large flow resistance and high threshold pressure gradient. A fractal model for calculating the threshold pressure gradient of tight oil reservoir is established considering the fractal dimension of the pore throat and the tortuosity. In this model, the rock is considered as a capillary bundle with different diameter distribution as obtained from high-pressure mercury injection measurements for tight rocks. The mathematical model expresses the fractal threshold pressure gradient as a function of ultimate shear stress (η0), pore throat fractal dimension (Df), tortuosity fractal dimension (DT), the maximum pore radius (rmax), the characteristic length of the core (L0) and the connate water saturation (Swi). For 27 tight cores obtained from Changqing oilfield, threshold pressure gradients were determined using the established model and compared with experimental results and a good fit was found especially for the rock with lower permeability. The relative error is less than 14% for all the rock tested and is only 1.77% for the cores with permeability in the range of 0.001~0.01mD. This model has the advantage of being able to check the impact of the connate water saturation on the threshold pressure gradient of tight rock, which is usually neglected in previous work. The results show that higher Swi results in largely increased threshold pressure gradient. This fractal model is of great importance in studying of the mechanism of tight oil flow in porous media.
Yunping Xi has completed his PhD in Structural Engineering from Northwestern University, Evanston, IL in the year of 1991. He has completed MS in Structural Engineering from Central Research Institute of Building and Construction in 1985 and has done B.S. in Civil Engineering from Beijing Institute of Civil Engineering and Architecture in 1982. Currently he is working as a professor of Structural Engineering & Structural Mechanics, Materials Science & Engineering department in University of Colorado at Boulder, USA
Well cement has been commonly used in wellbore environment, such as wells for oil and gas extraction and CO2 storage formation. For the safety of long-term operation of the wells, leakages in wellbore cement must be sealed. Nanoparticles in various slurries can be used to seal cracks in well cement. This study investigated the feasibility for developing an electrochemical method to inject nanoparticles into well cement not only to repair wellbore leakages and initial defects but also to extract the harmful ions (e.g. chlorides) simultaneously. Various experimental parameters were studied including different surface charges, types and sizes of nanoparticles and the intensity of injecting power supply. The new technology was developed and tested under the lab condition as well as a simulated wellbore condition. Some details for the technology to be used underground from inside of steel casing are under development so that it can be used for repairing the leakage of well cement for the oil and gas industry as well as for CO2 storage formations. Finite element models are being developed to simulate the nanoparticle injection and ionic transport processes of the technology..
Reza Javaherdashti holds a double degree in Materials Science and Metallurgical Engineering with a PhD in Corrosion and expertise in microbial corrosion. He has more than 20 years of industrial and academic experience. Dr. Reza isan approved instructor of ASME and SPE. In addition, He has more than 5000 hours of training industries around the globe about corrosion and microbial corrosion. He has also theorised corrosion knowledge management and have taught it globally to industries. Dr. Javaherdashti has several numbers of published papers in internationally recognised journals and books published by publishes n such as Elseviers, Springer and CRC Press/Taylor& Francis and Wiley.
A very efficient way to remove the debris collected with a pipeline is by pigging it. Use of intelligent pigs are also a very “smart” option for line pipe operators as this will allow them to also locate the location of defects (pitting). However good, intelligent pigging (or, as alternatively also called, smart pigging) does have some very serious shortcomings especially when it comes to the detection of the early stages of pitting induced by microbiologically influenced corrosion (MIC).
Some of these shortcomings are:
1) Smart pigs cannot detect pinholes. On the other hand, pinholes are characteristic of microbiologically influenced corrosion (MIC),
2) Intelligent pigs have been suspected of increasing the risk of hydrogen induced cracking (HIC) by 60%,
3) By enhancing EMIC (electrical microbiologically influenced corrosion) mechanisms, they may help magnetise corrosion –related bacteria (such as sulphate reducing bacteria-SRB) and result in typical corrosion rates of about 36 MPY.
In this presentation, the above points will be briefly explained. The aim of this presentation is to warn pipeline operators about probable cons of intelligent pigging in addition to their undeniable pros.