Characterization of Gas Reinjection at Karachaganak Field, Kazakhstan (Russian)

Kassenov, Alibek; Kaliyev, Bakytzhan

doi:10.2118/182589-ru

Cited by 3 publications

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A new empirical correlation of minimum miscibility pressure for produced gas reinjection

Fan

Zhang

et al. 2020

Energy Exploration & Exploitation

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Minimum miscible pressure is a key parameter to screen and design miscible gas injection projects. The aim of this paper is to establish a correlation with only a few input parameters to easily and accurately predict minimum miscible pressure for the reinjection of produced gas with high acidic components. First, the critical parameters of equation of state for each component of the crude oil were obtained through fitting pressure-volume-temperature (PVT) experimental results. Based on the analytically calculated minimum miscible pressures from mixing-cell method, an empirical correlation for predicting minimum miscible pressure in the displacement of crude oil by produced gas was regressed. Finally, the correlation’s accuracy was tested by comparing the minimum miscible pressures predicted from the new proposed correlation to other previous correlations and 20 experimental slim-tube minimum miscible pressures of 12 oil samples. The results indicate that the analytically calculated minimum miscible pressures from the mixing-cell method have a relative error of 0.5% compared to the slim-tube experiment results, which supports its reliability. Furthermore, the new proposed correlation is observed to be superior in terms of the average relative error being only 6.4% for all the 75 analytically calculated minimum miscible pressures and 20 experimental slim-tube minimum miscible pressures, which is lower than the average relative error obtained from other previous correlations.

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A new empirical correlation of minimum miscibility pressure for produced gas reinjection

Fan

Zhang

et al. 2020

Energy Exploration & Exploitation

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Challenges and Potentials for Sand Control Design and Management in Oil Reservoirs of Kazakhstan

Soroush

Hosseini

Roostaei

et al. 2020

SPE International Conference and Exhibition on Formation Damage Control

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Kazakhstan owns one of the largest global oil reserves (~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, clay content, porosity, permeability, gas cap, bottom water, 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, 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) with oil viscosity around 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 in comparison to the similar cases in North America. The complicated tectonic history, necessitates the geomechanical models to strategize the sand control especially in cased and perforated completion. These models are usually avoided in North America due to the less problematic conditions. Further investigation has shown that Inflow Control Devices (ICDs) could be utilized to limit the water breakthrough, as water coning is a common problem, which initiates 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.

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Multi-Stage Selective Completion and Acid Stimulation, Karachaganak Field, Kazakhstan

Naurzgaliyev,

Agambayev

2024

SPE Caspian Technical Conference and Exhibition

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Karachaganak is a giant oil, gas and condensate field located in north-western Kazakhstan, operated by Karachaganak Petroleum Operating b.v. (KPO b.v.). Karachaganak was discovered in 1979 and the production began in 1984. The field comprises Permian and Carboniferous reservoirs with complex geological and fluid properties. The reservoir fluids consist of gas-condensate and oil with strong compositional gradients. Since 1997, the focus of the field development has been on the oil rim with the objective of producing low GOR oil. This is being achieved by drilling sub-horizontal wells. The design of these wells is aimed at maximizing the reservoir contact to overcome the challenges of significant heterogeneity present in the field. It also allows to access to partially or fully isolated compartments associated with both reservoir heterogeneity and the presence of clinoforms formed during the evolution of Carboniferous platform. Initially horizontal wells were completed open-hole. Since 2011 new horizontal wells start being completed with multi-stage stimulation completions (swelling packers and sliding sleeves). Previous attempts at analyzing the benefit of multi-stage stimulation were hampered by a small population size for meaningful statistics. Today, the number of wells completed with multi-stage completions with available data is over 50. It's now therefore possible to make firmer conclusions regarding the potential benefits of multi-stage completions. Three specific areas of potential benefits of multi-stage completions over open holes have been identified and reviewed, these are as follows: Impact on well PI – Initial well PI (Deliverability);Flow Distribution – Percentage of wellbore contributing to flow (Enhanced sweep efficiency), andEase of well re-entry for rig-less operations – Data acquisition and remedial jobs. The available data indicate that multi-stage stimulations improve well productivity, downhole flow profile and the number of zones that contribute to flow. In addition to these primary benefits, there is an improvement in the ability to intervene in wells for data gathering. Based on these findings, it can be concluded that multi-stage completions result in a net positive contribution.

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Characterization of Gas Reinjection at Karachaganak Field, Kazakhstan (Russian)

Cited by 3 publications

References 0 publications

A new empirical correlation of minimum miscibility pressure for produced gas reinjection

A new empirical correlation of minimum miscibility pressure for produced gas reinjection

Challenges and Potentials for Sand Control Design and Management in Oil Reservoirs of Kazakhstan

Multi-Stage Selective Completion and Acid Stimulation, Karachaganak Field, Kazakhstan

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