Gadde, Prabhakara Rao2024-10-292024-10-291977-05-31https://hdl.handle.net/1808/35597M.S. University of Kansas, Chemical and Petroleum Engineering. 1977A small shallow eastern Kansas oil field was studied to determine whether the fluid flow pattern has been altered by high water injection pressures during water flooding. If the reservoir is highly fractured as indicated by very high permeabilities, then tertiary oil methods can not be applied successfully. The producers believe that the reservoir has been permanently fractured and thus damaged by use of excessive water injection pressures during waterflood. A test of the producer's hypothesis was undertaken using his water injection and production data in a reservoir fluid flow model that allowed one to adjust calculated production history through adjustment of the reservoir permeability. The optimal permeabilities for prediction of fluid flow were not close to the average pattern permeabilities measured through core analysis. This production history was predicted in a single phase, two dimensional mathematical model. Fluid flow was predicted in the later life of the waterflood when there was a high water oil ratio and essentially little oil production. A pressure history match was performed using a manual adjustment of permeability to give the best match. The permeability adjustment was performed on three relatively wide separated line drive patterns. In all three, the permeability yielding the closest match to the actual pressure profile was lower than the average permeability for the producing zone obtained from core analysis. This result was taken as partial evidence that severe fractures did not exist in the field.This item is protected by copyright and unless otherwise specified the copyright of this thesis/dissertation is held by the author.Oil field floodingOil reservoir engineeringFluid dynamicsThesisopenAccess