Long Z.,Xinjiang Uygur Autonomous Region Product Quality Supervision and Inspection Institute |
Li Z.,Tarim Oilfield |
Ma N.,CAS Lanzhou Institute of Chemical Physics |
Wu B.,CAS Lanzhou Institute of Chemical Physics
Bulletin of the Korean Chemical Society | Year: 2011
A self-assembled Al-bridged diiminopyridine-based ligand (3) was synthesized and characterized by FT-IR, ESI-MS and NMR spectroscopy. Electron spectral titrations were performed to confirm the formation of a novel trinuclear bis(imino)pyridyl iron(II) complex (4) upon addition of FeCl 2 into Al-bridged ligand 3 in methanol solution. Simultaneously, a typical bis(imino)pyridine-iron(II) complex (2) was synthesized and fully characterized. The X-ray crystal study of the iron(II) complex 2 disclosed a five-coordinate, distorted squarepyramidal structure with the tridentate N^N^N ligand and chlorides. The optimal molecular structure of 4 was obtained by means of molecular mechanics, which showed that each iron atom in the complex 4 is surrounded by two chlorides, a tridentate N^N^N ligand and one oxygen atom, supporting considerations about the possibility of six-coordinate geometry from MMAO or the ethylene access. A comparison of 4 with the reference 2 revealed a remarkable decrease of the catalytic activity and MMAO consumption (activity up to 0.41 × 103 kg molFe -1 h-1 bar-1, Al/Fe = 650 for 4 and 7.02 × 103 kg molFe -1 h-1 bar-1, Al/Fe = 1600 for 2).
Xiao G.,State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation |
Jingjing M.,Southwest Petroleum University |
Jiudi L.,Shanghai Offshore Petroleum Branch |
Yang H.,Shanghai Offshore Petroleum Branch |
Haiying W.,Tarim Oilfield
Society of Petroleum Engineers - SPETT Energy Conference and Exhibition 2012 | Year: 2012
Relative permeability is a critical parameter for evaluation of gas reservoir performances. Earlier works have indicated that relative permeabilities are markedly dependent on pore geometry, wettability, fluid saturation, saturation history, reservoir temperature, reservoir pressure, overburden pressure, rock types, porosity and permeability types. Some literatures have reported effect of reservoir temperature, reservoir pressure, overburden pressure on relative permeability. Because we are subjected to experiment conditions, it is very difficult for Dabei naturally fractured gas reservoir to measure relative permeability under 120 MPa abnormal high pressure and 145 Centigrade high temperature. In this paper, relative permeability of 12 cores without fracture and 3 cores with fracture during displacement of water by gas and displacement of gas by water in Dabei naturally fractured gas reservoirs under lower pressure and room temperature was measured. The results indicated that relative permeability in the process of displacement of water by gas is obviously different from that in the process of displacement of gas by water. Gas-water relative permeabilities of rock with fracture are higher than that of rock without fracture. In order to evaluate effect of abnormal high pressure and high temperature on relative permeability. A transformation model of gas-water relative permeability from experiment conditions to reservoir conditions was built up. A high temperature and high pressure wells for example, the effect of temperature and pressure on gas-water permeability was analog calculated, which the result indicated that water relative permeability cannot be effected by temperature and pressure, but gas relative permeability is. While gas relative permeability measured at experiment temperature and pressure which is beyond 10 times difference than the high pressure and high temperature at reservoir condition. It is suggested that it is unadvisable to predict gas reservoir performance by using gas-water relative permeability measured at experiment conditions. Copyright 2012, Society of Petroleum Engineers.
Zhao R.,Petrochina |
Zhang J.,Petrochina |
Tao Z.,Petrochina |
Tian J.,Tarim Oilfield |
And 7 more authors.
Society of Petroleum Engineers - International Petroleum Technology Conference 2013, IPTC 2013: Challenging Technology and Economic Limits to Meet the Global Energy Demand | Year: 2013
Sucker rod pumping system is the mechanical oil production method first used, up to now, it is also the most widely applied artificial lift method, however, three performance curves (displacement∼pump differential pressure, displacement ∼ horsepower, displacement ∼ efficiency) of sucker rod pumping (SRP), which are equivalent to those of electric submersible pump(ESP) and progressive cavity pump(PCP), are not available, increasing the complexity when node analyzing and designing of SRP well. As is known to all, when optimization design of SRP well, trial method is generally used and the operating time is long. Considering the interference of tubing, rod, wellbore fluid and piston pump when working, the subsurface system could be studied as a whole, and the relations between displacement and pump differential pressure, horsepower and pump differential pressure are researched. The dimensionless performance curves of SRP can be obtained based on API RP 11L standard. Three performance curves of subsurface system, namely the relation curves of displacement ∼pump differential pressure, displacement ∼ horsepower, displacement ∼ efficiency, are drawn for the first time. The characteristics of these performance curves are analyzed, showing these curves described in this article can effectively reflect the working characteristics of the subsurface system of SRP. The subsurface performance curves can be a useful tool for sensitivity analysis and optimization design of SRP system. These curves allow developing a general nodal analysis algorithm for any artificial lift pumping method and a more convenient optimization design algorithm for composite pumping system, such as Jet-Rod pumping system. Copyright 2013, International Petroleum Technology Conference.
Zhang B.,Tarim Oilfield |
Zhang H.,Tarim Oilfield |
Zhou Z.,Tarim Oilfield |
Liu Y.,Tarim Oilfield |
Lv Z.,Tarim Oilfield
Drilling Fluid and Completion Fluid | Year: 2012
Effects of temperature and pressure to rheology of drilling fluid are researched by FAN75, which is based on kinds of low middle and high densities sulfonated drilling fluid in Tarim oilfield. The experimental results show that when temperature and pressure change at the same time, rheology of the drilling fluid changes only with temperature, and the apparent viscosity drops down with temperature rises up below 180°C, rise simultaneously at 180-230°C, also the plastic viscosity drops down with temperature rises up, and the yield point drops down with temperature rises up within 100°C, both rise at 100-230°C.
Yin D.,Tarim Oilfield |
Ye Y.,Tarim Oilfield |
Li L.,Tarim Oilfield |
Liang H.,Tarim Oilfield |
Wang P.,Tarim Oilfield
Drilling Fluid and Completion Fluid | Year: 2012
The well Keshen7 is a deep exploration well located in foothill structural zone, with the salt bed formation depth of 7, 211 m. In this well, the high density whole oil base drilling fluid system is used to drill through salt bed formation, it is encountered high pressure salt water in depth of 7, 764 m, and the density of kill fluid is 2.55 g/cm3, however, a severe lost circulation occurs while killing well. In this situation, a kind of deposit isolation lost circulation control technology is applied that is cooperated with water-based lost circulation control mud and oil-based drilling fluid. The application shows that single normal LCM used either in water or oil based drilling fluid can not deal with the complex formations in well Keshen7, however, the deposit isolation lost circulation control technology can be used here successfully.