Challenges and Potentials for Sand and Flow Control and Management in the Sandstone Oil Fields of Kazakhstan: A Literature Review

Abstract

Summary Kazakhstan owns one of the largest global oil reserves (approximately 3%). This paper aims at investigating the challenges and potentials for production from weakly consolidated and unconsolidated oil sandstone reserves in Kazakhstan. We used the published information in the literature, especially those including comparative studies between Kazakhstan and North America. Weakly consolidated and unconsolidated oil reserves in Kazakhstan were studied in terms of the depth, pay-zone thickness, viscosity, particle-size distribution (PSD), clay content, porosity, permeability, gas cap, bottomwater, mineralogy, solution gas, oil saturation, and homogeneity of the pay zone. The previous and current experiences in developing these reserves were outlined. The stress condition was also discussed. Furthermore, the geological condition, including the existing structures, layers, and formations, were addressed for different reserves. Weakly consolidated heavy-oil reserves in shallow depths (less than 500-m true vertical depth) with oil viscosity of approximately 500 cp and thin pay zones (less than 10 m) have been successfully produced using cold methods; however, thicker zones could be produced using thermal options. Sand management is the main challenge in cold operations, while sand control is the main challenge in thermal operations. Tectonic history is more critical compared with the similar cases in North America. The complicated tectonic history necessitates geomechanical models to strategize the sand control, especially in cased and perforated completions. These models are usually avoided in North America because of the less-problematic conditions. Further investigation has shown that inflow-control devices (ICDs) could be used to limit the water breakthrough, because water coning is a common problem that begins and intensifies the sanding. This paper provides a review on challenges and potentials for sand control and sand management in heavy-oil reserves of Kazakhstan, which could be used as a guideline for service companies and operators. This paper could be also used as an initial step for further investigations regarding the sand control and sand management in Kazakhstan.

Evaluation of Quantitative Criteria for Triassic Reservoirs in the South Mangyshlak Basin

“…To identify carbonate reservoirs of Triassic deposits using well logging methods, it is difficult to identify the boundaries of the reservoirs using qualitative features due to the complex structure of the deposits and a number of factors that negatively affect the curves. Therefore, the technology of identifying reservoirs according to quantitative criteria that determine the "reservoir-non-reservoir" boundary at the static level is necessary to clarify the interpretation (Huang et al 2022;Ulmishek 2001;Al-Obaidi 2022;Soroush et al 2021). In order to determine the boundary values, correlation dependencies were constructed based on the parameters obtained from special laboratory core tests.…”

Rheological properties of polymer solutions and ways to improve the efficiency of development of high-viscosity oil fields in Uzbekistan

“…In recent years, oil fields with complex geological structure have been discovered in many oil and gas bearing regions of the world [1,2]. These fields are characterized by low oil saturated thickness of reservoirs, low filtration-capacity properties of reservoirs, high viscosity of reservoir oil and heterogeneity of productive horizons, etc [3].…”

“…One of the most important issues in increasing the degree of oil recovery from the subsurface is the study of structural and mechanical properties of polymer solutions, their influence on the filtration process in the reservoir and ways to regulate them. At present, a large amount of theoretical and experimental material has been accumulated to study the structural and mechanical properties and flow characteristics of non-Newtonian oils [1][2][3][4][5][6][7][8][9][10][11][12][13][14]. Studies have shown that during the development of wells that have opened deposits of heavy high-viscosity oils, there are complications associated with the difficulty of lifting oil to the surface.…”

“…Studies have shown that during the development of wells that have opened deposits of heavy high-viscosity oils, there are complications associated with the difficulty of lifting oil to the surface. The high content of asphaltene-resinous substances causes the manifestation of initial pressure gradients and relaxation processes in the oil-collector system during filtration, large pressure losses in wellhead communications and oil flow rates [1][2][3][4][5], leads to a significant reduction in oil recovery. A characteristic feature of heavy oil producing wells is also a sharp increase in water cut at the initial stage of development.…”

A New Elastoplastic 3D Sand Production Model for Fractured Gas Fields

“…This kind of volume failure is closely related to the production pressure difference and the degree of oil and gas reservoir depletion. Generally, it occurs in high pressure, high porosity and low strength oil and gas reservoirs [6,7]. Due to the increase of average stress caused by long-term production, when the average stress exceeds the upper limit pressure of volume damage, sand production will be caused.…”