Browsing by Subject "IFT"
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Item Control of intraflagellar transport : studies of the planar cell polarity effector Fuz, the small GTPase Rsg1, and the novel protein TTC29(2014-05) Brooks, Eric Robert; Wallingford, John B.Cilia are small microtubule based protrusions found on most cells of the vertebrate body. In humans, defects in the structure or function of cilia results in a large class of developmental and homeostatic diseases known collectively as the ciliopathies. Ciliogenesis is accomplished by the concerted action of a number of molecular pathways including the intraflagellar transport (IFT) system. IFT is a group of ~20 highly conserved proteins that assemble into large macromolecular complexes known as trains. These trains act to carry cargo bi-directionally between the cell body and ciliary tip, via interaction with the microtubule motors kinesin and dynein. IFT train dynamics are required for both cilia structure and function, however the controls on these dynamics are still incompletely understood. Here, I present the first platform for study of IFT dynamics within vertebrate multiciliated cells, an understudied population with critical functions in development and homeostasis. Using this platform, I demonstrate that the planar cell polarity effector protein Fuz is required for IFT dynamics via its control of the cytoplasmic localization of a subset of IFT proteins. Subsequently, I find that a Fuz binding partner, the putative small GTPase Rsg1, is also required for IFT protein localization and dynamics. Additionally, I describe a role for Rsg1 in basal body docking, one of the earliest events of ciliogenesis. Finally, I show that the poorly studied protein TTC29 is required for a specific subset of IFT dynamic behaviors. These data reveal novel regulatory motifs for ciliogenesis and demonstrate, specifically, the complexities of IFT regulation in the cytoplasm and within the cilium itself. Finally, they suggest that multiciliated cells provide a tractable platform for generating robust datasets for the investigation ciliary dynamics. Such studies are critical for informing our understanding of the molecular etiology of human ciliopathic diseases.Item Enhanced Oil Recovery in High Salinity High Temperature Reservoir by Chemical Flooding(2012-02-14) Bataweel, Mohammed AbdullahStudying chemical enhanced oil recovery (EOR) in a high-temperature/high-salinity (HT/HS) reservoir will help expand the application of chemical EOR to more challenging environments. Until recently, chemical EOR was not recommended at reservoirs that contain high concentrations of divalent cations without the need to recondition the reservoir by flooding it with less saline/ less hardness brines. This strategy was found ineffective in preparing the reservoir for chemical flooding. Surfactants used for chemical flooding operating in high temperatures tend to precipitate when exposed to high concentrations of divalent cations and will partition to the oil phase at high salinities. In this study amphoteric surfactant was used to replace the traditionally used anionic surfactants. Amphoteric surfactants show higher multivalent cations tolerance with better thermal stability. A modified amphoteric surfactant with lower adsorption properties was evaluated for oil recovery. Organic alkali was used to eliminate the water softening process when preparing the chemical solution and reduce potential scale problems caused by precipitation due to incompatibility between chemical slug containing alkali and formation brine. Using organic alkali helped in minimizing softening required when preparing an alkali-surfactant-polymer (ASP) solution using seawater. Solution prepared with organic alkali showed the least injectivity decline when compared to traditional alkalis (NaOH and Na2CO3) and sodium metaborate. Adding organic alkali helped further reduce IFT values when added to surfactant solution. Amphoteric surfactant was found to produce low IFT values at low concentrations and can operate at high salinity / high hardness conditions. When mixed with polymer it improved the viscosity of the surfactant-polymer (SP) solution when prepared in high salinity mixing water (6% NaCl). When prepared in seawater and tested in reservoir temperature (95?C) no reduction in viscosity was found. Unlike the anionic surfactant that causes reduction in viscosity of the SP solution at reservoir temperature. This will not require increasing the polymer concentration in the chemical slug. Unlike the case when anionic surfactant was used and more polymer need to be added to compensate the reduction in viscosity. Berea sandstone cores show lower recovery compared to dolomite cores. It was also found that Berea cores were more sensitive to polymer concentration and type and injectivity decline can be a serious issue during chemical and polymer injection. Dolomite did not show injectivity decline during chemical and polymer flooding and was not sensitive to the polymer concentration when a polymer with low molecular weight was used. CT scan was employed to study the displacement of oil during ASP, SP, polymer and surfactant flooding. The formation and propagation oil bank was observed during these core flood experiments. ASP and SP flooding showed the highest recovery, and formation and propagation of oil bank was clearer in these experiments compared to surfactant flooding. It was found that in Berea sandstone with a permeability range of 50 to 80 md that the recovery and fluid flow was through some dominating and some smaller channels. This explained the deviation from piston-like displacement, where a sharp change in saturation in part of the flood related to the dominated channels and tapered front with late arrival when oil is recovered from the smaller channels. It was concluded that the recovery in the case of sandstone was dominated by the fluid flow and chemical propagation in the porous media not by the effectiveness of the chemical slug to lower the IFT between the displacing fluid and oil.Item Experimental evaluation of surface treated nanoparticles and their effect on wettability alteration of carbonate surfaces and oil-brine interfacial tension(2016-08) Alramadan, Hamdi Ahmed; DiCarlo, David Anthony, 1969-; Mohanty, Kishore KThe alteration of rock surface wettability and the reduction of oil/brine interfacial tension enhances oil recovery from the reservoir. Most of the carbonate rock reservoirs around the world are oil-wet and changing their wettability may enhance oil recovery. Moreover, nanoparticles have presented a promising potential in enhanced oil recovery applications. An experimental study of contact angle changes upon exposure to nanoparticles on carbonate surfaces that are dispersed in brine solution has been conducted using various nanoparticle solutions, some of which were in-house synthesized. Also, interfacial tension measurements and calculations were implemented using the pendant drop method to study the effect of the invading nanoparticles solution. Nanoparticle concentrations were varied and progress was monitored with time. Effects of nanoparticle size, grafting coverage and mixed chemicals as well as observations are discussed. Two hypotheses were proposed for the wettability alteration mechanisms.Item Mobility control of chemical EOR fluids using foam in highly fractured reservoirs(2011-05) Gonzaléz Llama, Oscar; Nguyen, Quoc P.; Pope, Gary A.; Mohanty, KishoreHighly fractured and vuggy oil reservoirs represent a challenge for enhanced oil recovery (EOR) methods. The fractured networks provide flow paths several orders of magnitude greater than the rock matrix. Common enhanced oil recovery methods, including gases or low viscosity liquids, are used to channel through the high permeability fracture networks causing poor sweep efficiency and early breakthrough. The purpose of this research is to determine the feasibility of using foam in highly fractured reservoirs to produce oil-rich zones. Multiple surfactant formulations specifically tailored for a distinct oil type were analyzed by aqueous stability and foam stability tests. Several core floods were performed and targeted effects such as foam quality, injection rate, injection type, permeability, gas saturation, wettability, capillary pressure, diffusion, foam squeezing, oil flow, microemulsion flow and gravity segregation. Ultimately, foam was successfully propagated under various core geometries, initial conditions and injections methods. Consequently, fluids were able to divert to unswept matrix and improve the ultimate oil recovery.Item Probing the Roles that Intraflagellar Transport B Protiens Play on Stability, Assembly, and Localization of Complex B in Chlamydomonas ReinhardtII(2012-11-07) Richey, ElizabethIntraflagellar transport (IFT), the key mechanism for ciliogenesis, involves large protein particles moving bi-directionally along the entire ciliary length. IFT particles contain two large protein complexes, A and B, which are constructed with proteins in a core and several peripheral proteins. Prior studies have shown that in Chlamydomonas reinhardtii, IFT46, IFT52, and IFT88 directly interact with each other and are in a subcomplex of the IFT B core. However, ift46, bld1, and ift88 mutants differ in phenotype as ift46 mutants are able to form short flagella, while the other two lack flagella completely. In this study, we investigated the functional differences of these individual IFT proteins contributing to complex B assembly, stability, and basal body localization. We found that complex B is completely disrupted in bld1 mutant, indicating an essential role of IFT52 for complex B core assembly. Ift46 mutant cells are capable of assembling a relatively intact but highly unstable complex B. In contrast, in ift88 mutant cells the complex B core still assembles and remains stable, but the peripheral proteins no longer attach to the B core. Moreover, while complex A and the anterograde IFT motor FLA10 are localized normally to the transition fibers, complex B proteins instead are accumulated at the proximal ends of the basal bodies in ift88. Taken together, these results revealed a step-wise assembly process for complex B, and showed that the complex first localizes to the proximal end of the centrioles and then translocates onto the transition fibers via an IFT88-dependent mechanism. Protein interaction analyses such as the yeast two-hybrid assay in addition to identification and characterization of novel IFT complex B mutants will reveal a more complete picture of the architecture and function of IFT complex B.Item Simulation study of surfactant transport mechanisms in naturally fractured reservoirs(2010-08) Abbasi Asl, Yousef; Pope, Gary A.; Mohanty, Kishore K.Surfactants both change the wettability and lower the interfacial tension by various degrees depending on the type of surfactant and how it interacts with the specific oil. Ultra low IFT means almost zero capillary pressure, which in turn indicates little oil should be produced from capillary imbibition when the surfactant reduces the IFT in naturally fractured oil reservoirs that are mixed-wet or oil-wet. What is the transport mechanism for the surfactant to get far into the matrix and how does it scale? Molecular diffusion and capillary pressure are much too slow to explain the experimental data. Recent dynamic laboratory data suggest that the process is faster when a pressure gradient is applied compared to static tests. A mechanistic chemical compositional simulator was used to study the effect of pressure gradient on chemical oil recovery from naturally fractured oil reservoirs for several different chemical processes (polymer, surfactant, surfactant-polymer, alkali-surfactant-polymer flooding). The fractures were simulated explicitly by using small gridblocks with fracture properties. Both homogeneous and heterogeneous matrix blocks were simulated. Microemulsion phase behavior and related chemistry and physics were modeled in a manner similar to single porosity reservoirs. The simulations indicate that even very small pressure gradients (transverse to the flow in the fractures) are highly significant in terms of the chemical transport into the matrix and that increasing the injected fluid viscosity greatly improves the oil recovery. Field scale simulations show that the transverse pressure gradients promote transport of the surfactant into the matrix at a feasible rate even when there is a high contrast between the permeability of the fractures and the matrix. These simulations indicate that injecting a chemical solution that is viscous (because of polymer or foam or microemulsion) and lowers the IFT as well as alters the wettability from mixed-wet to water-wet, produces more oil and produces it faster than static chemical processes. These findings have significant implications for enhanced oil recovery from naturally fractured oil reservoirs and how these processes should be optimized and scaled up from the laboratory to the field.