Authors: A.Sh. Khaladov

Title of the article: Geological and Technological Indicators of High-Temperature Carbonate Reservoir Development Options: The Case of the Khankala Field in the Grozny Oil Region

Year: 2026, Issue: 3, Pages: 89-99

Branch of knowledge: 2.8.3 Mining and oil and gas geology, geophysics, mine surveying and subsurface geometry

Index UDK: 622.276

DOI: 10.26730/1999-4125-2026-3-89-99

Abstract: In the late-stage development of Mesozoic deposits in the Grozny oil region, where high-temperature carbonate reservoirs with a fractured-cavernous structure predominate, a comprehensive analysis of the technological and economic indicators of oil production development and intensification options is particularly important. This paper summarizes the results of well and reservoir studies at the Khankala field, a typical example of the Grozny oil region, taking into account the characteristics of the elastic-water drive regime, declining reservoir pressure, and increasing water cut. This article provides a detailed analysis of the geological and physical characteristics of the Upper Cretaceous reservoir at the Khankala field, including its depth (from 5,213 to 5,574 m), initial reservoir pressure (78.5 MPa with an anomaly coefficient of 1.5), reservoir temperature (+1,800 C), oil density (0.793 g/cm3), oil viscosity under reservoir conditions (0.16–0.186 mPa⋅s), and gas-oil ratio (908 m3/t). Particular attention is paid to the physicochemical properties of the oil (high paraffin content up to 9.5%, low resin and asphaltene concentration up to 1.5%) and their impact on production processes. This article examines methods of physicochemical stimulation of the near-wellbore zone, including clay-acid and emulsion treatments, as well as an assessment of capital and operating costs for a comparison of the baseline case using natural flow with the option of maintaining pressure by water injection. The methodological framework includes an analysis of production experience, thermohydrodynamic studies, and modeling of development scenarios. The obtained results demonstrate the advantage of the second option, which provides an oil recovery factor of up to 0.5 with a reduction in the reservoir life by two years, taking into account the thermal stability of reagents at temperatures of 140–180 °C. A comparative analysis of two reservoir development options is conducted: the baseline case—operation under natural filtration conditions—and the alternative option—maintaining reservoir pressure by injecting water into the reservoir. The obtained results demonstrate the advantage of the alternative development option: the oil recovery factor increases to 0.5; the reservoir life is reduced by two years; reservoir pressure is stabilized, which allows for maintaining flowing production with a water cut of up to 50%. The risk of complications associated with asphaltene deposits and corrosion is reduced. Based on an analysis of the Upper Cretaceous reservoir's development dynamics (cumulative oil production as of January 1, 2003—1,510.94 thousand tons, oil recovery factor of 0.422, current water cut of 1.6 %), recommendations for optimizing the waterflooding system were formulated. It was shown that a timely transition to reservoir pressure maintenance compensates for the decline in reservoir energy and ensures maximum reserve recovery. The study's results have practical significance for other fields in the Grozny oil region with similar geological and pressure-temperature conditions. The proposed development management approaches can be extrapolated to fields with high-temperature carbonate reservoirs, fracture structures, and high gas saturation.

Key words: high-temperature reservoir carbonate deposits bottomhole formation zone oil recovery factor oil production intensification Grozny oil region

Receiving date: 24.03.2026

Approval date: 15.06.2026

Publication date: 27.08.2026

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