Gas-water relative permeability measurement of high temperature and high pressure tight gas reservoirs

Fang, Jianlong; Guo, Ping; Xiao, Xiangjiao; Du, Jiapei; Dong, Chao; Xiong, Yao; Long, Fang

doi:10.1016/s1876-3804(15)60010-6

Cited by 42 publications

(18 citation statements)

References 7 publications

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“…As for the relative permeability of gas and water, Esmaeili et al (2020) use a newmethodology and conduct limited steady-state relative permeability measurements at different temperatures to confirm the validity of displacement-based relative permeability. Fang et al (2015) study the pattern of the relative permeability curves of gas and water in high-temperature, high-pressure tight gas reservoirs. Their research identifies that gas permeability under high temperature and high pressure is found to be higher than that under conventional conditions, which means high temperature and high pressure are in favor of gas flow.…”

Section: Introductionmentioning

confidence: 99%

Two-phase Flow Model and Productivity Evaluation of Gas and Water for Dual-Medium Carbonate Gas Reservoirs

et al. 2022

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Fluid flow in the dual-medium carbonate gas reservoir is characterized by stress sensitivity and non-Darcy flow effect. In order to accurately describe the unsteady flow of gas and water in the dual-medium gas reservoir, a two-phase flow model of gas and water is built. First, reservoir space and fluid flow characteristics of carbonate gas reservoirs are investigated, and the flow model that considers both the stress sensitivity and non-Darcy flow is built based on the fundamental flow theory, after fully investigating the reservoir space and fluid flow characteristics of carbonate gas reservoirs. Then, the perturbation theory is introduced, and the model is solved in the Laplace space, after which the obtained Laplace space analytical solution is converted into the real-space solution. Finally, the productivity evaluation model for the dual-medium gas reservoir with the gas-water two-phase flow is built, based on the flowing material balance method and Newton iteration. The presented productivity evaluation model is applied to analyze the effects of stress sensitivity and non-Darcy flow on the two-phase flow model of gas and water for the dual-medium gas reservoir and the reservoir productivity. The results indicate that a higher stress sensitivity coefficient is demonstrated to indicate higher stress sensitivity and accelerated production decline of the reservoir, while a lower non-Darcy flow effect coefficient represents a stronger non-Darcy effect and boosted drop of initial production of the reservoir. Hence, it is not reasonable to neglect the effects of stress sensitivity and non-Darcy flow during the evaluation of the productivity of a dual-medium carbonate gas reservoir. The model presented in this research provides important references for improving the recovery performance of dual-medium gas reservoirs.

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Section: Introductionmentioning

confidence: 99%

Two-phase Flow Model and Productivity Evaluation of Gas and Water for Dual-Medium Carbonate Gas Reservoirs

et al. 2022

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“…32,37 The G-W relative permeability of carbonate gas reservoirs is obtained by core experiments and mainly focuses on pore-and fracture-poretype reservoirs. 34,36,38 When considering the deficiencies of core experiments, it is meaningful to simulate the flow characteristics of the gas phase and G-W characteristics in REV models to comprehensively and thoroughly analyze the influence of pore structures.…”

Section: Introductionmentioning

confidence: 99%

“…In addition, 3D PNM can also be used to simulate gas–water two-phase (G-W) flow. G-W relative permeability characteristics contain a large amount of important information, which constitutes key data for reservoir development. − Some scholars have established a number of high-precision G-W relative permeability models, but they have mainly focused on sandstone, shale, and other reservoirs. , The G-W relative permeability of carbonate gas reservoirs is obtained by core experiments and mainly focuses on pore- and fracture-pore-type reservoirs. ,, When considering the deficiencies of core experiments, it is meaningful to simulate the flow characteristics of the gas phase and G-W characteristics in REV models to comprehensively and thoroughly analyze the influence of pore structures.…”

Section: Introductionmentioning

confidence: 99%

Influence of Pore Structure on Gas Flow and Recovery in Ultradeep Carbonate Gas Reservoirs at Multiple Scales

et al. 2021

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Ultradeep carbonate gas reservoirs are a major resource of interest in clean energy development, and complex pore structures and reservoir conditions with high-temperatures and pressures are great challenges to efficient development and experimental research. It is becoming increasingly imperative to study the influence of pore structure on gas flow and productivity under reservoir conditions. Taking an ultradeep carbonate gas reservoir in the eastern Sichuan Basin, SW China, as the target reservoir, the pore structure was accurately analyzed and classified by X-ray computed tomography scanning. On this basis, three representative pore network models were established to simulate and visually analyze the gas flow characteristics at the pore scale, which effectively supplemented and perfected previous core experiments and 2D visualization research. A high-temperature and high-pressure experimental platform was built, and the influence of pore structure, heterogeneity, and irreducible water saturation (SWI) on gas flow and recovery was studied quantitatively and qualitatively for the first time through improved core experiments. The results showed that fracture characteristics, pore connectivity, and water saturation are key factors affecting gas flow and depletion strategies, and cavities constitute the main reservoir space. Under no-water conditions, the final recovery nears 72.24%, and the influence of pore structure is not obvious. Under SWI conditions, the gas flow resistance increases, and the loss of the production rate is higher than 27% based on the similarity transformation; the lower the permeability or production pressure difference is, the higher the production rate loss will be. At the same time, irreducible water leads to significant recovery losses; the final recovery is between 57.95 and 71.10%, and the recovery loss of the pore-type reservoir is much higher than that of the fracture-type reservoir. In gas reservoir development, increasing permeability is conducive to improving the production rate and recovery, especially for ″high-porosity and low-permeability″ reservoirs. If the permeability is high enough, the production pressure difference should be controlled to avoid insufficient gas supply from far-well areas and reduce interlayer interference. Therefore, it is of great significance to promote coordinated development between multiple layers in the vertical direction and between near-well area and far-well areas in the horizontal direction.

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“…Dong et al [13] mentioned in their study that using unsteady-state method to study relative permeability is not adaptable since the end effect is obvious and longer samples are required, however, the length of most samples is less than 6 cm, so the end effect cannot be eliminated. At present, in most laboratories, the cores used for the measurement of relative permeability curves have two types: small cores (diameter is about 2.5cm) and full-diameter cores (diameter is about 6cm), the length of the cores is generally about 5-10cm [14][15][16], and very few researches use long cores to measure the relative permeability curves. Therefore, this paper selected the artificial long cores with similar characteristics as the outcrop cores of the Halfaya Oilfield for indoor simulation experiments.…”

Section: Introductionmentioning

confidence: 99%

Measurement of Relative Permeability Curves of Cores with Different Permeability and Lengths under Unsteady-State

Hu¹,

Luo²,

Wang³

et al. 2021

IJHT

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The oil-water and gas-water relative permeability curves are important reference data for the dynamic analysis and numerical simulation of oil and gas reservoir exploitation. Although the petroleum industry of China and other countries have formulated reference standards for the measuring methods of relative permeability of cores, they haven’t given the definite reference values of the core length, therefore we cannot know for sure whether different core length values are required in the measurement and whether the core length has an impact on the measurement results. In view of this gap, this paper conducted a research on the relative permeability of cores with different lengths. The core samples are artificial core with similar properties as the outcrop cores of the Halfaya Oilfield (Iraq), in our experiment, the oil-water and gas-water relative permeability curves of the sample cores were measured and the results suggest that, for the oil-water relative permeability curves, as the core length grows, the iso-permeability points move to the right, and they basically stabilize when the core length is greater than 20cm; as for gas-water relative permeability curves, in case of low-permeability cores, under constant injection pressure, as the core length grows, the iso-permeability points and the two-phase co-permeation areas present an obvious tendency of moving to the left, but when the core length is greater than 20cm, such tendency is not obvious, and the high-permeability cores do not have such characteristics. These results indicate that, the unsteady-state two-phase relative permeability measurement experiments obtained accurate results at a core length of about 20cm, which provided a reference for similar experiments in subsequent research.

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Gas-water relative permeability measurement of high temperature and high pressure tight gas reservoirs

Cited by 42 publications

References 7 publications

Two-phase Flow Model and Productivity Evaluation of Gas and Water for Dual-Medium Carbonate Gas Reservoirs

Two-phase Flow Model and Productivity Evaluation of Gas and Water for Dual-Medium Carbonate Gas Reservoirs

Influence of Pore Structure on Gas Flow and Recovery in Ultradeep Carbonate Gas Reservoirs at Multiple Scales

Measurement of Relative Permeability Curves of Cores with Different Permeability and Lengths under Unsteady-State

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