... During the nitrogen injection cycle it is necessary to measure following parameters: Indications of bottom-hole pressure and temperature (with an interval of 1 measurement in 1-10 sec., the pressure sensitivity should be no more than 0.0001 atm. It is necessary to register the pressure...

... because a higher volume of surfactant is consumed generating foam rather than adhering to the rock surface. The dynamic adsorption of the surfactant at reservoir conditions and proposed injection concentration was measured to be ~0.05 mg/g of rock. This adsorption corresponds to ~350 lbs./Acre-ft...

... gel technology injectivity injector communication application polymer gel decline curve analysis production rate fracture gel evaluation water cut production performance Introduction Production from tight oil assets and secondary recovery Abstract Thanks to the advancements...

... flow in porous media wassmuth polymer injection chemical flooding methods upstream oil & gas delamaide waterflooding polymer flood pilot polymer pengrowth corporation injection data concentration injection well injectivity resistance factor injection enhanced recovery fluid...

... (2) I = 2 π k k r w 0 h ∑ i = 1 n ∫ r i r i + 1 μ i r d r Abstract Reservoir simulators often predict poor injectivity in polymer enhanced oil recovery (EOR) projects because of the high polymer viscosity, which...

... In summary, there is strong evidence in the literature that foam can be used as a diverting agent to improve the CO 2 sweep efficiency and hence improve the overall oil recovery factor. However, as with any oil recovery method involving chemical injection ( Sheng 2013 ; Turta and Singhal 1998...

... reducing the impact of two of the key operational and economic challenges facing polymer enhanced oil recovery (EOR). The polymer employs a chemical strategy to render it resistant to shear during injection and in the high flux region at the sand face. In addition, the injection solution has a viscosity...

... for mitigating global warming as part of carbon capture, utilization, and storage (CCUS). Previous field tests with CO 2 foam report various results due to injectivity problems and the difficulty of attributing fluid displacement specifically to CO 2 foam. Thus, a more integrated multiscale methodology...

... Analysis of injection-production data in a per-pattern or per-well basis (e.g. injection and pressure vs. time, injection and production rates vs. time and water oil ratio vs. cumulative production; etc.), combined with the analysis of injection logging tests (ILT), stratigraphic correlations...

... of the expected flooded area A chase water where the water would switch from softened fresh to the current produced water Pilot Area Considering the faulting of the field, and the existing water flood development with peripheral water injection, and some injectors distributed within the rest...

... not require specific equipment excepted static mixers for the in-line inversion. Consequently, there is a significant load, foot print and CAPEX reduction for the injection process. In return, OPEX are higher (x2) because of the higher price of the polymer and the higher volumes to be transported (the polymer...

... In our previous publication ( Mukherjee, et al, 2014 ), we discussed our analysis of the baseline performance of the injector well 22SE30. The well 22SE30 is an open hole completion. During the baseline monitoring period prior to the foam pilot, it was observed that the CO 2 injection rate...

... and density. That pre-gel liquid is triggered to a gel by a pH change caused by external or internal initiation methods. One unique aspect of these silicate solutions is that they can be initiated by both the pre- and post-treatment injected CO 2 itself. Alternately, other external and internal initiators...

.... The Kuparuk River Field is a highly fractured and faulted, multi-layer sandstone reservoir located on the North Slope of Alaska. Large scale water injection in the field was initiated in 1981 and overall the field responded favorably to waterflood operations. In 1996, Kuparuk implemented a miscible WAG flood...

... Abstract Polymer injectivity is a critical parameter for implementation of polymer flood projects. An improved understanding of polymer injectivity is important in order to facilitate an increase in polymer EOR implementation. Typically, injectivity studies are performed using linear core...

... Abstract Polymer flooding by liquid polymers is an attractive technology for rapid deployment in remote locations. Liquid polymers are typically oil external emulsions with included surfactant inversion packages to allow for rapid polymer hydration. During polymer injection, a small amount...

... While it is necessary to inject a viscous chemical slug to maintain mobility control as oil is mobilized, increased viscosity can be a problem in the near-wellbore region. In contexts where horizontal wells or fracturing are feasible this may mitigate injectivity concerns. A more desirable...

... Abstract Foam can divert flow from higherto lower-permeability layers and thereby improve vertical conformance in gas-injection enhanced oil recovery. Recently, Kapetas et al. (2015) measured foam properties in cores from four sandstone formations ranging in permeability from 6 to 1900 md...

... runs in the injection well during the water injection phase showed a homogeneous injection profile over the reservoir interval. Well logs from new wells drilled within the pilot area provide additional insight with regards to the saturation distribution. Passive and partitioning tracers have been...

... Abstract Polymer flooding leads to enhanced oil recovery by accelerating oil production and improving sweep efficiency. However, owing to the higher viscosity, injectivity of polymer solutions is of some concern and is important to understand to predict incremental oil recoveries. Achieving...