Experiment and Simulation Study on the Special Phase Behavior of Huachang Near-Critical Condensate Gas Reservoir Fluid

Hou, Dali; Xiao, Yang; Pan, Yi; Sun, Lijun; Li, Kai

doi:10.1155/2016/2742696

Cited by 13 publications

(4 citation statements)

References 14 publications

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“…The increase in the CO 2 content is conducive to the formation of the condensate gas reservoir. The simulation results are consistent with the mercury-free visual DBR-PVT experiment by Hou et al [42]. The technology of CO 2 injection to enhance oil recovery in the later stage of condensate gas reservoir development is a practical application based on this theory.…”

Section: Discussion On Formation Mechanism Of Condensate Gas Reservoirssupporting

confidence: 86%

Phase Behavior Identification and Formation Mechanisms of the BZ19-6 Condensate Gas Reservoir in the Deep Bozhong Sag, Bohai Bay Basin, Eastern China

et al. 2021

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Significant developments have been observed in recent years, in the field of deep part exploration in the Bozhong Sag, Bohai Bay Basin in eastern China. The BZ19-6 large condensate gas field, the largest gas field in the Bohai Bay Basin, was discovered for the first time in a typical oil-type basin. The proven oil and gas geological reserves in the deeply buried hills of the Archean metamorphic rocks, amount to approximately 3 × 10 8 tons of oil equivalent. However, the phase behavior and genetic mechanisms of hydrocarbon fluids are still unclear. In this study, the phase diagram identification method and various empirical statistical methods, such as the block diagram method, φ 1 parameter method, rank number method, and Z -factor method were implemented to comprehensively identify the phase behavior types of the BZ19-6 condensate gas reservoir. The genetic mechanism of the BZ19-6 condensate gas reservoir was investigated in detail through analyses of physical properties of the fluid at high temperatures and pressures, organic geochemical characteristics of condensate oil and gas, and regional tectonic background. Consequently, this study is shown as follows: (1) The BZ19-6 condensate gas reservoir is a part of a secondary condensate gas reservoir with oil rings, formed synthetically since the Neogene period due to multiple factors, such as retrograde evaporation from deep burial and high temperature, inorganic CO2 charging from the deep mantle, and late natural gas invasion. (2) The hydrocarbon accumulation process of the BZ19-6 condensate gas reservoir is as follows: First, a large amount of oil is accumulated at the end of the lower Minghuazhen deposition (5 Ma BP); second, a large amount of natural gas is generated in the deep-source kitchen and mantle-derived inorganic CO2 charged into the early formed oil reservoirs at the end of the upper Minghuazhen deposition (2 Ma BP). As a result, the content of gaseous hydrocarbons in the hydrocarbon system of the reservoir increased, which led to large amounts of liquid hydrocarbons dissolved in gaseous hydrocarbons and significantly reduced the critical temperature of the hydrocarbon system. Therefore, existing secondary condensate gas reservoirs are formed when the critical temperature is lower than the formation temperature and it enters the critical condensate temperature range.

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Section: Discussion On Formation Mechanism Of Condensate Gas Reservoirssupporting

confidence: 86%

Phase Behavior Identification and Formation Mechanisms of the BZ19-6 Condensate Gas Reservoir in the Deep Bozhong Sag, Bohai Bay Basin, Eastern China

et al. 2021

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“…In addition to these theoretical approaches, empirical research methodologies include the utilization of the oil-rim discriminant method for reservoir-type determination. , Phase behavior experiments conducted under reservoir conditions reveal critical opalescence phenomena, indicative of near-critical condensate gas reservoir characteristics. − Observations of fluid stratification phenomena further reinforce the identification of near-critical behavior. , The investigation into fluid properties delineates significant distinctions between the studied reservoir and conventional condensate gas reservoirs in the Junggar Basin, while also highlighting similarities with typical near-critical condensate gas reservoirs in China. , …”

Section: Introductionmentioning

confidence: 92%

Phase Behavior of the Mid-deep Carboniferous Near Critical Condensate Gas Reservoir in Junggar Basin, China

Tuo,

Mensah,

Chen

et al. 2024

Energy Fuels

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This study investigates the phase behavior and fluid properties of a near-critical condensate gas reservoir located in the middeep Carboniferous formation of the Junggar Basin, China. Employing a combination of PVT techniques and empirical methods, including phase diagram analysis, liquid volume ratio assessment, and condensate content determination, we delineate the unique characteristics of this reservoir type. Experimental results reveal distinct phase phenomena, including (1) critical opalescence and fluid stratification, attributed to the significant density gradients near the critical region. (2) Comparative analysis with conventional condensate gas reservoirs underscores the atypical relationship between the dew point pressure and gas-oil ratio (GOR), crucial for reservoir management strategies. Furthermore, (3) empirical discrimination methods highlight the necessity of caution in classifying near-critical reservoirs, particularly concerning the presence of an oil rim. This research contributes novel insights into the understanding of near-critical condensate gas reservoirs, marking the discovery of the first such reservoir in the Junggar Basin.

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“…Research on the phase behavior of formation fluids figures prominently in the early stage of oilfield development. For deep oil and gas reservoirs, fluid types and properties are complex and variable under the conditions of high temperature and pressure (Hou et al, 2013;Tong et al, 2004). Therefore, it is crucial to accurately understand the changing patterns of fluids during oilfield development (Li et al, 2004).…”

Section: Introductionmentioning

confidence: 99%

Application of Fluid Phase Recovery Method in the Early Development of BZ26-6 Volatile Oil Field in Bohai Sea

Gao,

Zhang,

et al. 2023

GEP

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BZ26-6 Oilfield is a kind of deep metamorphic rock buried-hill volatile oilfield in Bohai Sea, China. Its early development plan is restricted due to the simultaneous production of oil and gas in large sections of reservoirs, unclear understanding of formation fluid properties and uncertainty of gas-oil interface. Through theoretical research on phase recovery and experimental analysis of crude oil phase characteristics in the original formation, characteristic parameters of the equilibrium condensate gas fluid are restored and calculated. Through the superimposed phase diagram of volatile oil and condensate gas, BZ26-6 Oilfield is determined to be a volatile oil reservoir with a condensate gas cap, with formation pressure and saturation pressure of 36.1 MPa, respectively. Based on the research results of oil-gas phase behavior characteristics, the thermodynamic equations and equation of state are jointly used to solve the problem, and the content change curves of each component at different depths are drawn. Combined with the sensitivity analysis of numerical simulation, the gas-oil interface is determined to be −3726 m above sea level. The fluid phase analysis software, Fluidmodeler, is used to simulate volatile oil degassing and condensate gas separation experiments. In combination with oil and gas production data obtained through the production test, the specific oil recovery index and the specific gas recovery index are determined to be 0.408 m 3 /(MPa•d•m) and 1195 m 3 /(MPa•d•m), respectively. And the reasonable production capacity prediction is conducted on the early development of BZ26-6 Oilfield. The research results can provide a theoretical basis for the efficient development of similar complex oil and gas reservoirs.

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Experiment and Simulation Study on the Special Phase Behavior of Huachang Near-Critical Condensate Gas Reservoir Fluid

Cited by 13 publications

References 14 publications

Phase Behavior Identification and Formation Mechanisms of the BZ19-6 Condensate Gas Reservoir in the Deep Bozhong Sag, Bohai Bay Basin, Eastern China

Phase Behavior Identification and Formation Mechanisms of the BZ19-6 Condensate Gas Reservoir in the Deep Bozhong Sag, Bohai Bay Basin, Eastern China

Phase Behavior of the Mid-deep Carboniferous Near Critical Condensate Gas Reservoir in Junggar Basin, China

Application of Fluid Phase Recovery Method in the Early Development of BZ26-6 Volatile Oil Field in Bohai Sea

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