Efficiency of horizontal wells in fields with highly viscous oil on the example of Tengri field

Due to the growing share of high-viscosity oils in Kazakhstan, task of their effective development is becoming more complicated. Development of terrigenous reservoirs that have a complex structure and contain high-viscosity oil lead to low rates of sampling and low values of oil recovery factor. Currently, technologies that ensure high efficiency in development of such deposits are very expensive. The paper considers a pilot section of the development horizon of cretaceous system of the Tengri field, drilled with vertical wells in accordance with current project document. Further the average characteristics of the parameters of horizontal wells are compared and measures are proposed to improve the efficiency of further operation of these wells.

High Viscosity Land Based Oil Flow Model

ABSTRACT Highly viscous oil does not behave the same as other regular liquid hydrocarbon mixtures. To evaluate the effects of a potential land-based blowout on the surrounding environment, RPS implemented a multi-step approach to simulate the trajectory and fate of high viscosity oil downslope flow. If spilled on land, initially warm oil cools and tends to gel, implying a non-Newtonian flow. To predict the behavior of high viscosity oil as it flows downslope, spreads and cools, RPS developed a new unique land-based spill model. The behavior of highly viscous crude oil has many similarities to volcanic lava flows, particularly the stark changes in oil viscosity and shear stress as the fluid cools. This study describes a “lava” flow numerical model developed to simulate the response of high viscosity oils. The viscous flow model is based on the lava model of Griffiths (2000) which simulates the unconfined motion of a Bingham fluid down a plane of constant slope. The model allows all physical and chemical parameters to vary continuously downslope. The lateral flow is assumed to cease when the cross-slope pressure gradient is balanced by the basal-yield stress also giving the height of the flow (H) on the center line of the flow as a function of shear stress. For oil flow motion the downslope pressure gradient must be greater than the oil shear stress and hence there is a critical height, based on the local oil shear stress and slope, below which there will be no downslope motion. An atmospheric heat transfer equation was applied to the oil surface as the surface boundary condition. The model was applied to a hypothetical on land release of highly viscous oil in a one-dimensional, downslope form, where the ground slope was assumed constant along the flow path. As the oil progresses downslope, its temperature was updated each time step in each cell and used to calculate new oil properties for density, specific heat, viscosity, and shear stress. The model results provide information about the rate and total distance travelled and time for the downslope flow to stop.

Nanoparticle cages as microreactors for producing acrolein from glycerol in the liquid phase

A highly viscous oil phase forms a smaller Pickering emulsion, increasing the acrolein yield from glycerol by intensified mass transfer.

PROGRESSING CAVITY PUMP AS A SOLUTION TO INCREASE PRODUCTIVITY OF HIGHLY VISCOUS OIL WELLS WITH SAND PRODUCTION: A CASE STUDY OF FIELD X

Major oil fi elds in Indonesia have been experiencing massive decline in production, accompanied by excessive sand production that is not benefi cial to the integrity of the production system. Sand production has been known to increase the potential of corrosion, reducing lifetime of well equipment, and also known to shut in wells completely due to sand buildup in wellbore. Progressive Cavity Pump has been proposed as a solution to withstand these complications, due to its nature that can handle many types of fl uids and even produced solid. The idea is then tested to a mature Alabaster fi eld where the majority of the wells have been shut in due to excessive sand problem and low productivity. It is worth nothing that after installing the PCP, production modeling indicates possibility of sustaining production through the application of PCP, where the production increases around 120 STB/ day. Although PCP has proven its effectiveness, it is important to note that auxiliary sand mitigation techniques is required to maintain facilities integrity after several years of production.