... for an extended period of time between Test #1 and Test #2 to recover all of the injected water and to return the near-wellbore pore space to the same initial oil saturation. Doing so ensures that the SWCT tests are evaluating the displacement efficiency of the produced water and the polymer solution relative...

... polymer resistance factor injectivity test permeability evaluation injection pressure transient testing polymer injection scleroglucan polymer injectivity test result scleroglucan polymer solution viscosity high temperature reservoir conditions Background The oil and gas industry...

... Abstract The objective of the study was to estimate which was the effective mobility of a polymer solution injected in an extra heavy oil reservoir, also try to stablish if there was a reduction on effective permeability as injection progressed, and finally estimate the mobility ratio between...

... the polymer solution and compromise the economics if not dealt with adequately. In this paper we will review the existing projects and discuss the offshore deployment philosophies for polymer injection. Then, the focus will be on brown fields and the differences between polymer emulsion and powder forms...

... experiments, the polymer concentrations were adjusted such that the in situ viscosities of each solution were comparable at the expected in situ average shear rates (see Vik et al, 2018 ). The rheological properties of the injected "polymer" solutions in the dynamic pore network model (DPNM), were also...

... the rock are crucial for determining the degradation undergone (degradation being defined as the irreversible loss of viscosity). Our aim is is to establish predictive laws for the degradation of polymer solutions flowing through porous media and for the associated flow thickening which can mobility...

... to enhance oil recovery significantly. However, polymer solution is a continuous phase viscous fluid, and it cannot distinguish the large or small pore, which causes the damage in low permeability layer. Furthermore, it leads to the "entry profile inversion" phenomenon and the reduction of injection...

... transport in porous media (~200 mD) without inducing any face plugging. flow in porous media concentration stainless cylinder enhanced recovery polymer pressure drop upstream oil & gas coreflood 2 experiment stability glutaraldehyde scleroglucan solution scleroglucan polymer solution...

... and formulation fluid loss control fluid dynamics in-situ rheology shear copolymer degradation viscosity retention concentration stability relaxation time polymer viscosity hydrolysis adsorption polymer solution static adsorption test apparent viscosity Introduction Polymer flooding...

... (Levitt et al. 2013), we demonstrated a surprisingly high oil recovery with low concentration (and viscosity) partially hydrolyzed polyacrylamide (HPAM) polymer solutions of only 3 cP displacing a 2000 cP oil. Additional experiments with more viscous as well as non-elastic viscosifying agents demonstrated...

... yields unrepresentative results from the time delay and fluid quality changes during transport. coreflood Upstream Oil & Gas enhanced recovery pressure drop polymer flooding characterization polymer solution filtration ratio experiment liquid polymer injection chemical flooding...

... Abstract This paper examines oil displacement as a function of polymer solution viscosity during laboratory studies in support of a polymer flood in the Cactus Lake reservoir in Canada. When displacing 1610-cp crude oil from field cores (at 27°C and 1 ft/d), oil recovery efficiency increased...

... of the pipe (m)  D = diameter of the pipe (m)  V = average fluid velocity (m/s) Tests were carried outusing only water in the first place and then polymer solution at different concentrations, viscosities and flow rates (20 m3/d, 40 m3/d, 60 m3/d and 80 m3/d) making the polymer solution flow in 12...

... through shear regimes greater than 150,000 s −1 . Scleroglucan polymer solution showed less than 25% drop in viscosity after exposure to 115 °C for six months. No change in viscosity was observed at 95 °C after one year. Scleroglucan has no compatibility issues through 6 months (at 37, 85, and 95 °C...

... and likely has more than one cause. Polymer solutions may reduce injectivity over time because the polymer is incompletely hydrated and contains oligomers or microgels, or because the individual polymer molecules are too large to enter the formation, or because of some minerology-dependent, adverse...

... and emulsified oil droplet. During its transport through porous media, the polymer emulsion shows high flow resistance and its injection pressure exhibits an obviously creeping fluctuation increasing phenomenon as compared to surfactant emulsion and sheared polymer solution. chemical flooding methods...

... Oil & Gas concentration well pg-34 reduction injection pg-34 pattern injectivity water injection reservoir incremental oil production polymer solution incremental recovery factor Introduction Palogrande-Cebu Field (PG-CB) is a Colombian field located in the south west...

... segment. enhanced recovery effective length experiment pressure gradient flow in porous media flow rate HPAM Injection Rate Upstream Oil & Gas core 1 mechanical degradation mobility reduction core 3 polymer solution molecular weight chemical flooding methods Fluid Dynamics...

...Crossflow between Layers Abstract This paper addresses two questions for polymer flooding. First, what polymer solution viscosity should be injected? A base-case reservoir-engineering method is present for making that decision, which focuses on waterflood mobility ratios and the permeability...

... enhanced recovery Brine Upstream Oil & Gas siderite concentration retention value chemical flooding methods hpam retention experiment degradation anaerobic condition polymer solution society of petroleum engineers retention sodium dithionite adsorption polymer retention...