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Journal articles on the topic 'Gas condensate reservoirs'

Author: Grafiati

Published: 4 June 2021

Last updated: 25 July 2025

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1

Chen, H. L., S. D. Wilson, and T. G. Monger-McClure. "Determination of Relative Permeability and Recovery for North Sea Gas-Condensate Reservoirs." SPE Reservoir Evaluation & Engineering 2, no. 04 (1999): 393–402. http://dx.doi.org/10.2118/57596-pa.

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Summary Coreflood experiments on gas condensate flow behavior were conducted for two North Sea gas condensate reservoirs. The objectives were to investigate the effects of rock and fluid characteristics on critical condensate saturation (CCS), gas and condensate relative permeabilities, hydrocarbon recovery and trapping by water injection, and incremental recovery by subsequent blowdown. Both CCS and relative permeability were sensitive to flow rate and interfacial tension. The results on gas relative permeability rate sensitivity suggest that gas productivity curtailed by condensate dropout c

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2

Hu, Wen Ge, Xiang Fang Li, Xin Zhou Yang, Ke Liu Wu, and Jun Tai Shi. "Energy Control in the Depletion of Gas Condensate Reservoirs with Different Permeabilities." Advanced Materials Research 616-618 (December 2012): 796–803. http://dx.doi.org/10.4028/www.scientific.net/amr.616-618.796.

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Energy control (i. e. pressure control) has an obvious effect on development effect in the depletion of gas condensate reservoir. Phase change behavior and characteristics of the relative pemeability in gas condensate reservoirs were displayed in this paper, then pressure and condensate distribution were showed through reservoir simulation. Finally, the influence of the pressure drop on condensate distribution and condensate oil production in gas condensate reservoirs with different permeabilities was studied. Results show that: First, in high / moderate permeability gas condensate reservoirs,

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3

PC, Nwankwo. "Efficient Model for Estimation of Dew Point Pressure in Gas Condensate Systems." Petroleum & Petrochemical Engineering Journal 8, no. 4 (2024): 1–8. https://doi.org/10.23880/ppej-16000397.

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Gas condensate reservoirs are a special class of gas reservoirs with temperatures which plot between the critical point temperature Tc and the cricondentherm Tcric on a Pressure–Temperature (P-T) phase diagram. The reservoirs’ produced streams are characterized by relatively, low C1 : C2 +ratio, implying compositions with significant fractions of high molecular weight (C2 +) hydrocarbons, called Natural Gas Liquids (NGLs). NGLs exist as gas at reservoir conditions of high pressures and temperatures but as liquids, called condensates (or distillates) at separator conditions, havinge higher mark

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4

Zhang, Lijun, Fuguo Yin, Bin Liang, Shiqing Cheng, and Yang Wang. "Pressure Transient Analysis for the Fractured Gas Condensate Reservoir." Energies 15, no. 24 (2022): 9442. http://dx.doi.org/10.3390/en15249442.

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Gas condensate reservoirs exhibit complex thermodynamic behaviors when the reservoir pressure is below the dew point pressure, leading to a condensate bank being created inside the reservoir, including gas and oil condensation. Due to natural fractures and multi-phase flows in fractured gas condensate reservoirs, there can be an erroneous interpretation of pressure-transient data using traditional multi-phase models or a fractured model alone. This paper establishes an analytical model for a well test analysis in a gas condensate reservoir with natural fractures. A three-region composite model

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5

Tu, Hanmin, Ruixu Zhang, Ping Guo, et al. "The Impact of Condensate Oil Content on Reservoir Performance in Retrograde Condensation: A Numerical Simulation Study." Energies 17, no. 22 (2024): 5750. http://dx.doi.org/10.3390/en17225750.

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This study investigates the complex dynamics of retrograde condensation in condensate gas reservoirs, with a particular focus on the challenges posed by retrograde condensate pollution, which varies in condensate oil content and impacts on reservoir productivity. Numerical simulations quantify the distribution of condensate oil and the reduction in gas-phase relative permeability in reservoirs with 100.95 g/m3, 227.27 g/m3, and 893.33 g/m3 of condensate oil. Unlike previous studies, this research introduces an orthogonal experiment to establish a methodology for studying the dynamic sensitivit

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Katanova, R. K., E. I. Inyakina, M. D. Z. Alsheikhly, and I. I. Krasnov. "Estimation of the Influence of Oil Flows on the Formation Losses of Condensate During the Development of Multi-Layer Deposits." IOP Conference Series: Earth and Environmental Science 988, no. 2 (2022): 022067. http://dx.doi.org/10.1088/1755-1315/988/2/022067.

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Abstract During the development of multilayer oil and gas condensate fields, the production of condensate is influenced by the associated oil. Analysis of field data showed that the cause of oil flows is the outstripping decrease in reservoir pressure in the gas condensate section in comparison with oil zones. Thus, incoming heavy oil fractions into a gas condensate reservoir have a negative impact on reservoir losses of hydrocarbons, including the final condensate recovery factor. Many years of experience in the development of such fields showed that the bulk of the presence of associated oil

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7

Panja, Palash, and Milind Deo. "Factors That Control Condensate Production From Shales: Surrogate Reservoir Models and Uncertainty Analysis." SPE Reservoir Evaluation & Engineering 19, no. 01 (2015): 130–41. http://dx.doi.org/10.2118/179720-pa.

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Summary Rapid development of shales for the production of oils and condensates may not be permitting adequate analysis of the important factors governing recovery. Understanding the performance of shales or tight oil reservoirs producing condensates requires numerically extensive compositional simulations. The purpose of this study is to identify important factors that control production of condensates from low-permeability plays and to develop analytical “surrogate” models suitable for Monte Carlo analysis. In this study, the surrogate reservoir models were second-order response surfaces func

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8

Noshad, Shar. "Model the Reservoir Fluid Behavior and Pressure Maintenance Through Gas Cycling in Gas Condensate Reservoir." ENGINEERING SCIENCE AND TECHNOLOGY INTERNATIONAL RESEARCH JOURNAL 2, no. 3 (2018): 8. https://doi.org/10.5281/zenodo.13295007.

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Compositional reservoirs (gas-condensate) have complex behaviour. Gas-condensate reservoirs are critical reservoirs in nature. Gas-condensate reservoir has single phase fluid above the dew-point pressure and below the dewpoint pressure has two-phase fluids. In depletion method, reservoir pressure decreases below the dew-point pressure at that pressure two phase-fluid start to form gas and condensate in the reservoir and liquid accumulate around the wellbore that is condensate banking. The accumulation of condensate around the wellbore that blocks the perforated channels and

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9

Vadim Bogopolsky, Ali Nagiyev, Vadim Bogopolsky, Ali Nagiyev. "METHODS FOR INCREASING THE CONDENSATE RECOVERY COEFFICIENT WHEN DEVELOPING GAS CONDENSATE FIELDS." PAHTEI-Procedings of Azerbaijan High Technical Educational Institutions 36, no. 01 (2024): 332–42. http://dx.doi.org/10.36962/pahtei36012024-332.

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This article will discuss methods for increasing the condensate recovery coefficient and the concept of condensate recovery. Gas condensate is a cold hydrocarbon reservoir that includes natural gas as well as liquid hydrocarbons, often in the form of liquid condensate. During reservoir extraction, liquids are mixed from mixtures of light hydrocarbons (eg methane, ethane, propane) and denser liquid hydrocarbons (known as condensates). Gas condensates are found in underground reservoirs, where temperature and pressure conditions allow the gas to condense into liquid form as it moves from the for

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Zhu, Kai, Lingjie Gao, and Fengrui Sun. "Numerical Simulation Study on Optimization of Development Parameters of Condensate Gas Reservoirs." Processes 12, no. 10 (2024): 2069. http://dx.doi.org/10.3390/pr12102069.

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Due to the retrograde condensation phenomenon in the development process, the fluid phase change is complex, and it becomes particularly difficult to accurately describe the fluid flow characteristics and residual oil and gas distribution characteristics during the development of condensate gas reservoirs. It is difficult to select the development program and subsequent dynamic adjustment for the efficient, reasonable, and sustainable development of condensate gas reservoirs. In this paper, the phase characteristics of condensate gas reservoirs are clarified; the basic fluid model is created b

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Bilotu Onoabhagbe, Benedicta, Paul Russell, Johnson Ugwu, and Sina Rezaei Gomari. "Application of Phase Change Tracking Approach in Predicting Condensate Blockage in Tight, Low, and High Permeability Reservoirs." Energies 13, no. 24 (2020): 6551. http://dx.doi.org/10.3390/en13246551.

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Prediction of the timing and location of condensate build-up around the wellbore in gas condensate reservoirs is essential for the selection of appropriate methods for condensate recovery from these challenging reservoirs. The present work focuses on the use of a novel phase change tracking approach in monitoring the formation of condensate blockage in a gas condensate reservoir. The procedure entails the simulation of tight, low and high permeability reservoirs using global and local grid analysis in determining the size and timing of three common regions (Region 1, near wellbore; Region 2, c

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Gromova, E. A., and S. A. Zanochuev. "Monitoring the composition of gas condensate well streams based on samples taken from multiphase flow meters." Oil and Gas Studies, no. 5 (October 31, 2021): 127–39. http://dx.doi.org/10.31660/0445-0108-2021-5-127-139.

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The article highlights the relevance of reliable estimation of the composition and properties of reservoir gas during the development of gas condensate fields and the complexity of the task for reservoirs containing zones of varying condensate content. The authors have developed a methodology that allows monitoring the composition of gas condensate well streams of similar reservoirs. There are successful examples of the approach applied in Achimov gas condensate reservoirs at the Urengoy oil and gas condensate field. The proposed approach is based on the use of the so-called fluid factors, whi

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13

Wang, Ping, Wenchao Liu, Wensong Huang, Chengcheng Qiao, Yuepeng Jia, and Chen Liu. "Dynamic Productivity Prediction Method of Shale Condensate Gas Reservoir Based on Convolution Equation." Energies 16, no. 3 (2023): 1479. http://dx.doi.org/10.3390/en16031479.

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The dynamic productivity prediction of shale condensate gas reservoirs is of great significance to the optimization of stimulation measures. Therefore, in this study, a dynamic productivity prediction method for shale condensate gas reservoirs based on a convolution equation is proposed. The method has been used to predict the dynamic production of 10 multi-stage fractured horizontal wells in the Duvernay shale condensate gas reservoir. The results show that flow-rate deconvolution algorithms can greatly improve the fitting effect of the Blasingame production decline curve when applied to the

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14

Meng, Xingbang, Zhan Meng, Jixiang Ma, and Tengfei Wang. "Performance Evaluation of CO2 Huff-n-Puff Gas Injection in Shale Gas Condensate Reservoirs." Energies 12, no. 1 (2018): 42. http://dx.doi.org/10.3390/en12010042.

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When the reservoir pressure is decreased lower than the dew point pressure in shale gas condensate reservoirs, condensate would be formed in the formation. Condensate accumulation severely reduces the commercial production of shale gas condensate reservoirs. Seeking ways to mitigate condensate in the formation and enhance both condensate and gas recovery in shale reservoirs has important significance. Very few related studies have been done. In this paper, both experimental and numerical studies were conducted to evaluate the performance of CO2 huff-n-puff to enhance the condensate recovery in

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15

Shams, Bilal, Jun Yao, Kai Zhang, and Lei Zhang. "Sensitivity analysis and economic optimization studies of inverted five-spot gas cycling in gas condensate reservoir." Open Physics 15, no. 1 (2017): 525–35. http://dx.doi.org/10.1515/phys-2017-0060.

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AbstractGas condensate reservoirs usually exhibit complex flow behaviors because of propagation response of pressure drop from the wellbore into the reservoir. When reservoir pressure drops below the dew point in two phase flow of gas and condensate, the accumulation of large condensate amount occurs in the gas condensate reservoirs. Usually, the saturation of condensate accumulation in volumetric gas condensate reservoirs is lower than the critical condensate saturation that causes trapping of large amount of condensate in reservoir pores. Trapped condensate often is lost due to condensate ac

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16

Sun, Boyu, Guofang Zhang, Fuping Wang, Xu Hu, and Xiulian Wang. "Analysis of Migration Characteristics of Supercritical CO₂ and Mechanism of Oil and Gas Production in Condensate Gas Reservoirs." Journal of Physics: Conference Series 2592, no. 1 (2023): 012019. http://dx.doi.org/10.1088/1742-6596/2592/1/012019.

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Abstract At present, circulating gas injection is the most effective development method for condensate gas reservoirs in China, but the phenomenon of dry gas overlap has seriously affected the development effect of circulating gas injection in condensate gas reservoirs, while CO2 injection is used to drive gas, which can make CO2 widely used in removing retrograde condensation of condensate gas reservoirs, improving the development effect of gas reservoirs. This paper by comparing the migration laws of injected dry gas and injected CO2 obtains that the dry gas with a smaller density flows to t

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17

Esmaeili, A., L. E. Garzón Rojas, A. Crodrigues Nogueira, et al. "Effect of Gas Injection on the Enhancement of Condensate Recovery in a Gas Condensate Reservoir." Journal of Physics: Conference Series 2594, no. 1 (2023): 012060. http://dx.doi.org/10.1088/1742-6596/2594/1/012060.

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Abstract So far, many methods have been used to increase production from gas condensate reservoirs, but in general, all these methods can be placed in two groups:1) Methods of maintaining pressure or preventing pressure drop; 2) Creating chemical changes in reservoir fluids to improve production mechanisms due to capillary forces.Also, many of the methods used have realized both of the above purposes and at the same time while maintaining the reservoir pressure (or preventing pressure drop) also change the chemical physical properties of the reservoir. One of these methods is gas injection. Wh

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Wu, Yiming, Kun Yao, Yan Liu, et al. "Experimental Study on Enhanced Condensate Recovery by Gas Injection in Yaha Condensate Gas Reservoir." Geofluids 2021 (October 14, 2021): 1–15. http://dx.doi.org/10.1155/2021/7698970.

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A condensate gas reservoir is an important special oil and gas reservoir between oil reservoir and natural gas reservoir. Gas injection production is the most commonly used development method for this type of gas reservoir, but serious retrograde condensation usually occurs in the later stages of development. To improve the recovery efficiency of condensate oil in the middle and late stages of production of a condensate gas reservoir, a gas injection parameter optimization test study was carried out, taking the Yaha gas condensate reservoir in China as an example. On the premise that the physi

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Wu, Yiming, Kun Yao, Yan Liu, et al. "Experimental Study on Enhanced Condensate Recovery by Gas Injection in Yaha Condensate Gas Reservoir." Geofluids 2021 (October 14, 2021): 1–15. http://dx.doi.org/10.1155/2021/7698970.

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A condensate gas reservoir is an important special oil and gas reservoir between oil reservoir and natural gas reservoir. Gas injection production is the most commonly used development method for this type of gas reservoir, but serious retrograde condensation usually occurs in the later stages of development. To improve the recovery efficiency of condensate oil in the middle and late stages of production of a condensate gas reservoir, a gas injection parameter optimization test study was carried out, taking the Yaha gas condensate reservoir in China as an example. On the premise that the physi

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20

Hou, Dali, Yang Xiao, Yi Pan, Lei Sun, and Kai Li. "Experiment and Simulation Study on the Special Phase Behavior of Huachang Near-Critical Condensate Gas Reservoir Fluid." Journal of Chemistry 2016 (2016): 1–10. http://dx.doi.org/10.1155/2016/2742696.

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Due to the special phase behavior of near-critical fluid, the development approaches of near-critical condensate gas and near-critical volatile oil reservoirs differ from conventional oil and gas reservoirs. In the near-critical region, slightly reduced pressure may result in considerable change in gas and liquid composition since a large amount of gas or retrograde condensate liquid is generated. It is of significance to gain insight into the composition variation of near-critical reservoir during the depletion development. In our study, we performed a series ofPVTexperiments on a real near-c

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21

Alexander, Ofori Mensah, Amorin Richard, and Osei Harrison. "Model Investigation of Low Salinity Brine Injection on Gas-Condensate Recovery in a Sandstone Reservoir: Effect of Calcium and Sodium Ions." International Journal of Innovative Science and Research Technology 7, no. 8 (2022): 1757–64. https://doi.org/10.5281/zenodo.7098418.

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There are many technical challenges associated with the recovery of valuable condensates from gas-condensate reservoirs. While some condensates are immobile far from the production well, others can accumulate close to the producer wellbore area. As a result, such valuable condensates are either not produced or, in some cases, their accumulation might choke the production well, lowering gas productivity. Maintaining reservoir pressure has long been a means of dealing with this problem. This, however, only functions as a temporary solution because the drop-out and immobile condensate production

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22

Liu, Yang, Yi Pan, Yang Sun, and Bin Liang. "Experimental Study on the Control Mechanism of Non-Equilibrium Retrograde Condensation in Buried Hill Fractured Condensate Gas Reservoirs." Processes 11, no. 11 (2023): 3242. http://dx.doi.org/10.3390/pr11113242.

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During the depletion development of condensate gas reservoirs, when the formation pressure drops below the dew point pressure, the condensate oil and natural gas systems are in the non-equilibrium state of foggy retrograde condensation. The rational use of the non-equilibrium phase characteristics of the foggy retrograde condensation phenomenon during the development process will be beneficial to the recovery of condensate oil and natural gas. In order to clarify the retrograde condensation control mechanism during the non-equilibrium depletion development of condensate gas reservoirs, the pha

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Ayala, Luis F., Turgay Ertekin, and Michael A. Adewumi. "Compositional Modeling of Retrograde Gas-Condensate Reservoirs in Multimechanistic Flow Domains." SPE Journal 11, no. 04 (2006): 480–87. http://dx.doi.org/10.2118/94856-pa.

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Summary A multimechanistic flow environment is the result of the combined action of a Darcian flow component (the macroscopic flow of the phase caused by pressure gradients) and a Fickian-like or diffusive flow component (diffusive flow caused by molecular concentration gradients) taking place in a hydrocarbon reservoir. The present work presents the framework needed for the assessment of the impact of multimechanistic flow on systems where complex fluid behavior—such as that of retrograde gas-condensate fluids—requires the implementation of compositional reservoir simulators. Because of the c

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Onoabhagbe, Gomari, Russell, Ugwu, and Ubogu. "Phase Change Tracking Approach to Predict Timing of Condensate Formation and its Distance from the Wellbore in Gas Condensate Reservoirs." Fluids 4, no. 2 (2019): 71. http://dx.doi.org/10.3390/fluids4020071.

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Production from gas condensate reservoir poses the major challenge of condensate banking or blockage. This occurs near the wellbore, around which a decline in pressure is initially observed. A good sign of condensate banking is a rise in the gas–oil ratio (GOR) during production and/or a decline in the condensate yield of the well, which leads to considerable reductions in well deliverability and well rate for gas condensate reservoirs. Therefore, determining the well deliverability of a gas condensate reservoir and methods to optimize productivity is paramount in the industry.

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Zhang, Lijun, Wengang Bu, Nan Li, Xianhong Tan, and Yuwei Liu. "Numerical Simulation of Multiarea Seepage in Deep Condensate Gas Reservoirs with Natural Fractures." Energies 16, no. 1 (2022): 10. http://dx.doi.org/10.3390/en16010010.

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Research into condensate gas reservoirs in the oil and gas industry has been paid much attention and has great research value. There are also many deep condensate gas reservoirs, which is of great significance for exploitation. In this paper, the seepage performance of deep condensate gas reservoirs with natural fractures was studied. Considering that the composition of condensate gas changes during the production process, the component model was used to describe the condensate gas seepage in the fractured reservoir, modeled using the discrete fracture method, and the finite element method was

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Zhang, Youyin, Chuanjun Yi, Zongfang Hu, Qiang Zheng, Miaomiao Wang, and Yong Ye. "Exploration and Practice of Synergistic and Efficient Development Technology for Gas-Capped Condensate Gas Reservoirs and Oil Rings." Journal of Physics: Conference Series 2834, no. 1 (2024): 012077. http://dx.doi.org/10.1088/1742-6596/2834/1/012077.

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Abstract The oil-ringed condensate gas reservoir is one of the more unique and complex types of oil and gas reservoirs. The stable oil and gas interface is crucial for the efficient development of such reservoirs, and the fundamental means of addressing the issue lies in maintaining the dynamic balance between the gas cap and the oil ring. In this paper, we address issues such as the rapid decline in oil ring production, gas cap breakthrough, and increased condensate oil loss exposed during the development of the R carbonate reservoir in the Caspian Sea Basin of Kazakhstan. Using reservoir eng

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Matkivskyi, S. V., O. V. Burachok, and L. I. Matiishyn. "Evaluation of the gas recycling duration on the hydrocarbon recovery from gas condensate fields." Archives of Materials Science and Engineering 117, no. 2 (2022): 57–69. http://dx.doi.org/10.5604/01.3001.0016.1776.

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Optimization of formation pressure maintenance technologies in the development of gas condensate fields with a high initial content of condensate in the reservoir gas using numerical modelling. A study on the efficiency of dry gas injection for pressure maintenance in gas condensate fields was performed with the help of numerical 3D models. Key technological indicators of the reservoir development were calculated for the dry gas injection period of 12, 24, 36, 48, and 60 months. The results are presented as plots for the parameters in a study. Based on the results of the studies, it was found

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Abeshi, P. U., T. I. Oliomogbe, J. O. Emegha, V. A. Adeyeye, and Y. O. Atunwa. "Application of Deep Neural Network-Artificial Neural Network Model for Prediction Of Dew Point Pressure in Gas Condensate Reservoirs from Field-X in the Niger Delta Region Nigeria." Journal of Applied Sciences and Environmental Management 27, no. 11 (2023): 2629–35. http://dx.doi.org/10.4314/jasem.v27i11.35.

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Reservoirs of natural gas and gas condensate have been proposed as a potential for providing affordable and cleaner energy sources to the global population growth and industrialization expansion simultaneously. This work evaluates reservoir simulation for production optimization using Deep Neural network - artificial neural network (DNN-ANN) model to predict the dew point pressure in gas condensate reservoirs from Field-X in the Niger Delta Region of Nigeria. The dew-point pressure (DPP) of gas condensate reservoirs was estimated as a function of gas composition, reservoir temperature, molecul

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Lopez Jimenez, Bruno A., and Roberto Aguilera. "Flow Units in Shale Condensate Reservoirs." SPE Reservoir Evaluation & Engineering 19, no. 03 (2016): 450–65. http://dx.doi.org/10.2118/178619-pa.

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Summary Recent work has shown that flow units characterized by process or delivery speed (the ratio of permeability to porosity) provide a continuum between conventional, tight-gas, shale-gas, tight-oil, and shale-oil reservoirs (Aguilera 2014). The link between the various hydrocarbon fluids is provided by the word “petroleum” in “Total Petroleum System” (TPS), which encompasses liquid and gas hydrocarbons found in conventional, tight, and shale reservoirs. The work also shows that, other things being equal, the smaller pores lead to smaller production rates. There is, however, a positive sid

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Liu, Wenchao, Yuejie Yang, Chengcheng Qiao, Chen Liu, Boyu Lian, and Qingwang Yuan. "Progress of Seepage Law and Development Technologies for Shale Condensate Gas Reservoirs." Energies 16, no. 5 (2023): 2446. http://dx.doi.org/10.3390/en16052446.

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With the continuous development of conventional oil and gas resources, the strategic transformation of energy structure is imminent. Shale condensate gas reservoir has high development value because of its abundant reserves. However, due to the multi-scale flow of shale gas, adsorption and desorption, the strong stress sensitivity of matrix and fractures, the abnormal condensation phase transition mechanism, high-speed non-Darcy seepage in artificial fractures, and heterogeneity of reservoir and multiphase flows, the multi-scale nonlinear seepage mechanisms are extremely complicated in shale c

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Sabea, Husam, Jalal A. Al-Sudani, and Omar Al-Fatlawi. "Geological Model of the Khabour Reservoir for Studying the Gas Condensate Blockage Effect on Gas Production, Akkas Gas Field, Western Iraq." Iraqi Geological Journal 55, no. 1C (2022): 80–96. http://dx.doi.org/10.46717/igj.55.1c.7ms-2022-03-26.

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The Khabour reservoir, Ordovician, Lower Paleozoic, Akkas gas field which is considered one of the main sandstone reservoirs in the west of Iraq. Researchers face difficulties in recognizing sandstone reservoirs since they are virtually always tight and heterogeneous. This paper is associated with the geological modeling of a gas-bearing reservoir that containing condensate appears while production when bottom hole pressure declines below the dew point. By defining the lithology and evaluating the petrophysical parameters of this complicated reservoir, a geological model for the reservoir is b

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Chukwuka, Peace, Ikechukwu Oscar Ogali, Wilfred Chinedu Okologume, and Adamu Dawaki. "A MODEL FOR FORECASTING DEW POINT PRESSURE IN NIGER DELTA CONDENSATE RESERVOIRS USING CONSTANT VOLUME DEPLETION TESTS DATA." Romanian Journal of Petroleum & Gas Technology 5 (76), no. 1 (2024): 19–32. http://dx.doi.org/10.51865/jpgt.2024.01.02.

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The dew point pressure plays a critical role in developing gas condensate reservoirs. It is a crucial factor used in fluid characterisation, performance estimation of gas reservoirs, and design of production systems. However, the composition of gas condensate fluid varies from one location to another, and thus, empirical correlations have been developed to determine the dew point pressure without conducting routine tests. As a result, correlations that are solely useful in the region where they were developed and analysed are developed. This work developed an empirical correlation using data f

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Serhii, Krivulya, Matkivskyi Serhii, Kondrat Oleksandr, and Bikman Efim. "Approval of the technology of carbon dioxide injection into the V-16 water driven reservoir of the Hadiach field (Ukraine) under the conditions of the water pressure mode pages 1–2." TECHNOLOGY AUDIT AND PRODUCTION RESERVES 6, no. 1(56) (2020): 1–12. https://doi.org/10.15587/2706-5448.2020.217780.

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<em>The object of research is water-driven gas-condensate reservoirs. Using the main hydrodynamic modeling tools Eclipse and Petrel from Schlumberger (USA), the study was carried out to improve the existing technologies for the displacement of residual gas reserves by carbon dioxide from the water-driven gas-condensate reservoirs. The carbon dioxide injection technology was tested in the V-16 reservoir of the Hadiach oil and gas condensate field (Ukraine). According to the study results, it was found that due to the injection of non-hydrocarbon gas, the cumulative water production are reduced

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Shen, Guo-Tao, and Ren-Shi Nie. "Modelling Pressure Dynamic of Oil–Gas Two-Phase Flow in Three-Zone Composite Double-Porosity Media Formation with Permeability Stress Sensitivity." Energies 18, no. 9 (2025): 2209. https://doi.org/10.3390/en18092209.

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In view of the flow zoning phenomenon existing in condensate gas reservoirs and the complex pore structure and strong heterogeneity of carbonate rock reservoirs, this study investigates the pressure dynamic behavior during the development process of such gas reservoirs by establishing corresponding models. The model divides the reservoir into three zones. The fluid flow patterns and reservoir physical property characteristics in the three regions are different. In particular, the fracture system in zone 1 has permeability stress sensitivity. The model is solved and the sensitivity analysis of

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Song, Heng, Zi Fei Fan, Lun Zhao, and An Gang Zhang. "Gas Cap and Oil Rim Collaborative Development Technique Policy of Carbonate Reservoir with Condensate Gas Cap." Advanced Materials Research 734-737 (August 2013): 1381–90. http://dx.doi.org/10.4028/www.scientific.net/amr.734-737.1381.

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Zhanazhol oilfield is a large-scale complicated carbonated oil and gas field , Гnorth is the main oil and gas reservoirs of the oil field, The gas cap index is 0.38, the gas cap on a high condensate content. Reservoir development for nearly 25 years, exploitation in the past only to oil ring. Due to insufficient water injection in early age, the oil ring pressure dropped substantially, and the formation pressure to maintain the level of only 58%. For oil and gas reservoirs with a condensate gas cap, gas cap and oil ring at the same pressure system, with the decline in the pressure of the oil r

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Henderson, G. D., A. Danesh, D. H. Tehrani, S. Al-Shaidi, and J. M. Peden. "Measurement and Correlation of Gas Condensate Relative Permeability by the Steady-State Method." SPE Reservoir Evaluation & Engineering 1, no. 02 (1998): 134–40. http://dx.doi.org/10.2118/30770-pa.

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Abstract High pressure core flood experiments using gas condensate fluids in long sandstone cores have been conducted. Steady-state relative permeability points were measured over a wide range of condensate to gas ratio's (CGR), with the velocity and interfacial tension (IFT) being varied between tests in order to observe the effect on relative permeability. The experimental procedures ensured that the fluid distribution in the cores was representative of gas condensate reservoirs. Hysteresis between drainage and imbibition during the steady-state measurements was also investigated, as was the

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Zhang, Yufeng, Yefei Chen, Anzhu Xu, et al. "Calculation Method of Three-Phase Productivity of Horizontal Well in Water-Bearing Condensate Gas Reservoir." Energies 17, no. 12 (2024): 2932. http://dx.doi.org/10.3390/en17122932.

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Condensate gas reservoirs are a special kind of reservoir because of the presence of multiphase flow in their production. The accurate calculation of the multiphase flow productivity in horizontal wells is of great significance for reservoir development. In this study, the total pseudopressure and the equivalent total flow are defined to solve the multiphase nonlinear problem in the oil–gas–water three-phase control flow equation, and to establish a three-phase productivity equation considering the non-Darcy effect. It provides a solution for the three-phase productivity calculation of horizon

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Kusochkova, E. V., I. M. Indrupskiy, and V. N. Kuryakov. "Distribution of the Initial Fluid Composition in an Oil-Gas-Condensate Reservoir with Incomplete Gravity Segregation." IOP Conference Series: Earth and Environmental Science 931, no. 1 (2021): 012012. http://dx.doi.org/10.1088/1755-1315/931/1/012012.

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Abstract It is known that initial composition of the hydrocarbon fluid in a petroleum reservoir changes significantly with depth due to the influence of gravity and geothermal gradient. Classical models of these phenomena are based on the assumption of equilibrium (quasiequilibrium) distribution of component concentrations in the gravity field with the presence of stationary thermodiffusional flux. However, there are typical situations in gas condensate reservoirs when the quasi-equilibrium conditions are not met. For example, this is true if immobile residual oil exists in the reservoir or fo

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Huang, Quan Hua, and Xing Yu Lin. "Prediction of water breakthrough time in horizontal Wells in edge water condensate gas reservoirs." E3S Web of Conferences 213 (2020): 02009. http://dx.doi.org/10.1051/e3sconf/202021302009.

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Horizontal Wells are often used to develop condensate gas reservoirs. When there is edge water in the gas reservoir, it will have a negative impact on the production of natural gas. Therefore, reasonable prediction of its water breakthrough time is of great significance for the efficient development of condensate gas reservoirs.At present, the prediction model of water breakthrough time in horizontal Wells of condensate gas reservoir is not perfect, and there are mainly problems such as incomplete consideration of retrograde condensate pollution and inaccurate determination of horizontal well

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Mott, R. E., A. S. Cable, and M. C. Spearing. "Measurements of Relative Permeabilities for Calculating Gas-Condensate Well Deliverability." SPE Reservoir Evaluation & Engineering 3, no. 06 (2000): 473–79. http://dx.doi.org/10.2118/68050-pa.

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Summary Well deliverability in many gas-condensate reservoirs is reduced by condensate banking when the bottomhole pressure falls below the dewpoint, although the impact of condensate banking may be reduced due to improved mobility at high capillary number in the near-well region. This paper presents the results of relative permeability measurements on a sandstone core from a North Sea gas-condensate reservoir, at velocities that are typical of the near-well region. The results show a clear increase in mobility with capillary number, and the paper describes how the data can be modeled with emp

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Mohan, Jitendra, Gary A. Pope, and Mukul M. Sharma. "Effect of Non-Darcy Flow on Well Productivity of a Hydraulically Fractured Gas-Condensate Well." SPE Reservoir Evaluation & Engineering 12, no. 04 (2009): 576–85. http://dx.doi.org/10.2118/103025-pa.

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Summary Hydraulic fracturing is a common way to improve productivity of gas-condensate wells. Previous simulation studies have predicted much larger increases in well productivity than have been actually observed in the field. This paper shows the large impact of non-Darcy flow and condensate accumulation on the productivity of a hydraulically fractured gas-condensate well. Two-level local-grid refinement was used so that very small gridblocks corresponding to actual fracture width could be simulated. The actual fracture width must be used to accurately model non-Darcy flow. An unrealistically

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Safari-Beidokhti, Mohsen, Abdolnabi Hashemi, Reza Abdollahi, Hamed Hematpur, and Hamid Esfandyari. "Numerical Well Test Analysis of Condensate Dropout Effects in Dual-Permeability Model of Naturally Fractured Gas Condensate Reservoirs: Case Studies in the South of Iran." Mathematical Problems in Engineering 2021 (May 7, 2021): 1–10. http://dx.doi.org/10.1155/2021/9916914.

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Naturally fractured reservoirs (NFR) represent an important percentage of worldwide hydrocarbon reserves and production. The performance of naturally fractured gas condensate reservoirs would be more complicated regarding both rock and fluid effects. In contrast to the dual-porosity model, dual-porosity/dual-permeability (dual-permeability) model is considered as a modified model, in which flow to the wellbore occurs through both matrix and fracture systems. Fluid flow in gas condensate reservoirs usually demonstrates intricate flow behavior when the flowing bottom-hole pressure falls below th

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Burachok, Oleksandr. "Enhanced Gas and Condensate Recovery: Review of Published Pilot and Commercial Projects." Nafta-Gaz 77, no. 1 (2021): 20–25. http://dx.doi.org/10.18668/ng.2021.01.03.

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The majority of the Ukrainian gas condensate fields are in the final stage of development. The high level of reservoir energy depletion has caused significant in situ losses of condensed hydrocarbons. Improving and increasing hydrocarbon production is of great importance to the energy independence of Ukraine. In this paper, a review of the pilot and commercial enhanced gas and condensate recovery (EGR) projects was performed, based on published papers and literature sources, in order to identify those projects which could potentially be applied to the reservoir conditions of Ukrainian gas cond

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Dr., Mehrdad Alemi. "Optimal Productivity Index from Gas Pay Zones with FAF Test." Indian J ournal of Petroleum Engineering (IJPE) 3, no. 1 (2023): 8–12. https://doi.org/10.54105/ijpe.B1915.053123.

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<strong>Abstract: </strong>Gas Condensate reservoirs are hydrocarbon liquid dissolved in saturated natural gas that comes out of solution when the pressure drops below the dew point. Condensate liquid saturation can build up near a well because of draw down below the dew point pressure, ultimately restricting the flow of gas. This phenomenon is called as "condensate blockage or banking". This improves the mobility of the gas with respect to the oil. If the gas does not have sufficient energy to carry the liquid to surface, then "liquid loading" in the wellbore occurs. If liquid falls back down

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Wang, Zhenliang, Shengdong Xiao, Feilong Wang, Guomin Tang, Liwen Zhu, and Zilong Zhao. "Phase Behavior Identification and Formation Mechanisms of the BZ19-6 Condensate Gas Reservoir in the Deep Bozhong Sag, Bohai Bay Basin, Eastern China." Geofluids 2021 (July 2, 2021): 1–19. http://dx.doi.org/10.1155/2021/6622795.

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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 identificatio

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Chen, Junqing, Xiongqi Pang, and Zhenxue Jiang. "Controlling factors and genesis of hydrocarbons with complex phase state in the Upper Ordovician of the Tazhong Area, Tarim Basin, China." Canadian Journal of Earth Sciences 52, no. 10 (2015): 880–92. http://dx.doi.org/10.1139/cjes-2014-0209.

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Seven hydrocarbon reservoirs have been discovered to date in the Upper Ordovician of the Tazhong Area, a region in which hydrocarbon phase distribution is complex. In the present study, the genesis and controlling factors of the hydrocarbons with complex phase in the Tazhong Area were investigated on the basis of the geological and geochemical conditions required for the formation and distribution of hydrocarbon reservoirs, integrated with the source rock geochemistry, natural gas and oil properties, and oil and gas reservoir fluid tests PVT (i.e., pressure, volume, and temperature tests). The

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Goldthorpe, W. H., and J. K. Drohm. "APPLICATION OF THE BLACK OIL PVT REPRESENTATION TO SIMULATION OF GAS CONDENSATE RESERVOIR PERFORMANCE." APPEA Journal 27, no. 1 (1987): 370. http://dx.doi.org/10.1071/aj86032.

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Special attention must be paid to the generation of PVT parameters when applying conventional black oil reservoir simulators to the modelling of volatile oil and gas-condensate reservoirs. In such reservoirs phase behaviour is an important phenomenon and common approaches to approximating this, via the black oil PVT representation, introduce errors that may result in prediction of incorrect recoveries of surface gas and condensate. Further, determination of production tubing pressure drops for use in such simulators is also prone to errors. These affect the estimation of well potentials and re

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Alaa, Zeinab, Chis Timur-Vasile, and Osorio Pozo Alejandro. "A Short Review about Predicting the Dew Point Pressure for Gas Condensate Reservoirs by Empirical Correlations." International Journal of Engineering Research and Reviews 11, no. 3 (2023): 31–40. https://doi.org/10.5281/zenodo.8195450.

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<strong>Abstract:</strong> The following essay compiles different correlations found in the literature to determine the dew point pressure of gas condensate reservoirs. An evaluation and comparison study of these methods is performed for 150 gas samples from different regions and literature sources. The tested models were: Shokir, Nemeth-Kennedy, Elsharkawy, Ahmadi, Kamari and Okpo Nnadozie. The before mentioned models were chosen because they are function of reservoir temperature, gas composition, molecular weight, and specific gravity of the heavy component (C7+). The best model representing

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Alemi, Dr Mehrdad, and Hossein Jalalifar. "Optimal Productivity Index from Gas Pay Zones with FAF Test." Indian Journal of Petroleum Engineering 3, no. 1 (2023): 8–12. http://dx.doi.org/10.54105/ijpe.b1915.053123.

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Abstract:

Gas Condensate reservoirs are hydrocarbon liquid dissolved in saturated natural gas that comes out of solution when the pressure drops below the dew point. Condensate liquid saturation can build up near a well because of draw down below the dew point pressure, ultimately restricting the flow of gas. This phenomenon is called as “condensate blockage or banking”. This improves the mobility of the gas with respect to the oil. If the gas does not have sufficient energy to carry the liquid to surface, then “liquid loading” in the wellbore occurs. If liquid falls back down the wellbore, the liquid p

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He, Xujiao, Liangdong Zhao, Xinqian Lu, et al. "A Critical Review Using CO2 and N2 of Enhanced Heavy-Oil-Recovery Technologies in China." Applied Sciences 12, no. 24 (2022): 12585. http://dx.doi.org/10.3390/app122412585.

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Thermal recovery technology is generally suitable for shallow lays due to the higher thermal loss for the deep heavy-oil reservoirs. Non-thermal recovery technologies, such as the non-condensate gas injection technology, are not limited by the reservoir depth and could be extensively applied for the heavy-oil reservoir. Many experimental studies and field applications of non-condensate gas injection have been conducted in heavy-oil reservoirs. The injected non-condensate gas could achieve dynamic miscibility with heavy oil through multiple contacts, which has a significant viscosity-reduction

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