Water invasion and remaining gas distribution in carbonate gas reservoirs using core displacement and NMR

Guo, Chengfei; Li, Hua-Bin; Tao, Ye; Lang, Liyuan; Niu, Zhong-xiao

doi:10.1007/s11771-020-4314-1

Cited by 11 publications

(9 citation statements)

References 25 publications

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“…(3) Dissolving water seals and water locks caused by water invasion in the reservoir. This is mainly through the injection of gas (CO 2 or N 2 ) [83][84][85][86][87][88][89] into the formation to pass through the isolated gas area sealed by the water, forming flow channels again, and reducing the flow resistance of natural gas. Gas can enter the low permeability layer that water cannot; moreover, due to its compressibility and expansion, gas plays a role in plugging, assisting drainage, displacement, and gas lift when energy is released, which helps to overcome the constraint of capillary force, thus discharging reverse osmotic water and reducing the water locking effect [90][91][92][93].…”

Section: Development Countermeasures Of Fractured-porous Water-bearin...mentioning

confidence: 99%

Physical Simulation Experimental Technology and Mechanism of Water Invasion in Fractured-Porous Gas Reservoir: A Review

Zhou

et al. 2021

Energies

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In the development process for a fractured-porous gas reservoir with developed fracture and active water, edge water or bottom water easily bursts rapidly along the fracture to the production well, and the reservoir matrix will absorb water, reducing the gas percolation channel and increasing the gas phase percolation resistance of the reservoir matrix, therefor reducing the stable production capacity and recovery efficiency of the gas reservoir. For this reason, this paper investigates physical simulation experimental technology and mechanisms as reported by both domestic and foreign scholars regarding water invasion in fractured-porous gas reservoirs. In this paper, it is considered that the future trend and focus of water invasion experiments will be to establish a more realistic three-dimensional physical model on the basis of fine geological description, combined with gas reservoir well pattern deployment and production characteristics, and to fully consider the difference between horizontal and vertical water invasion along the reservoir side; at the same time, dynamic parameters such as model pressure field and water saturation field can be obtained in real time. Based on this understanding of the water invasion mechanism of fractured-porous gas reservoirs, we propose the next research direction and the development countermeasures such as water controls, drainage, and dissolved water seals and water locks to combat water invasion in reservoirs, along with the injection of gas to replenish formation energy, etc., so as to slow down and control the influence of water invasion.

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Section: Development Countermeasures Of Fractured-porous Water-bearin...mentioning

confidence: 99%

Physical Simulation Experimental Technology and Mechanism of Water Invasion in Fractured-Porous Gas Reservoir: A Review

Zhou

et al. 2021

Energies

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“…Fault-solution oil reservoirs are independent of the regional unconformity levels and structural locations. Hydrocarbon is filled vertically along the Tongyuan fault zone to form reservoirs and migrates in a "T" shape along with the fracture network sys-tem related to the fault zone, which are the characteristics of vertical transportation and accumulation, segmented accumulation, and differential accumulation [3,4]. The main zones of fault-solution reservoirs are characterized by high oil and gas resources, with high productivity of oil wells.…”

Section: Introductionmentioning

confidence: 99%

Residual Oil Distribution Pattern in a Fault-Solution Carbonate Reservoir and Countermeasures to Improve Oil Development Effectiveness

et al. 2022

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Because of the strong random distribution of fractures and caves, fault-solution carbonate reservoirs exhibit significantly different flow mechanisms and development methods from conventional carbonate reservoirs. Natural elastic and edge-bottom water flooding are the main processes for developing fault-solution reservoirs. The rapid decline in production and the complex residual oil distribution are major challenges for oil production. This study is aimed at (1) assessing the residual oil migration law, (2) determining the residual oil distribution characteristics, and (3) identifying the main controlling factors using numerical simulation, to provide suggestions for enhancing oil recovery. The results showed that fractures are the main channel for oil flow and the main path of bottom water coning in the fault-solution reservoirs. The channeling of bottom water along high-angle fractures is the main reason for the decline in oil production. In addition, bottom water coning and gas/water injection are the key factors affecting the distribution of residual oil, while the irregular development of fractures and caves is the main factor causing diversified distribution patterns of the residual oil. The residual oil distribution patterns of fault-solution reservoirs include 4 types, namely, attic, bottom water rising and blocking, separated fracture-cavity, and pores near high-conductivity channel types. For tapping the potential of residual oil, several approaches can be used, namely, deploying new wells or using sidetracking of old wells in the loft and the separated fracture-cavity reservoirs. In addition, the attic residual oil type can also be developed using drainage oil recovery or gas injection for oil replacement. Liquid lift pump, water shutoff, and water cone restrain can also be used to tap residual oil from rising bottom water. Optimizing profile control and water shutoff measures and adjusting the injection and production relationship can be effective approaches for developing residual oil in the pores and cracks beside the high diversion channel.

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“…Because water invasion will reduce the recovery efficiency of water gas reservoirs, it is of great significance to clarify the water invasion mechanism and put forward an effective water invasion risk identification method for the efficient development of water gas reservoirs. Fang Feifei et al [4], Zubarev et al [5], Guo Chengfei et al [6], and Sheng Ruyan et al [7] all show that the influencing factors of water invasion in water gas reservoirs are complex, and reservoir heterogeneity is one of the main factors. Liu Huaxun et al [8] believed that the stronger the reservoir heterogeneity was, the faster the formation water advanced and the earlier the water appeared in the gas well.…”

Section: Introductionmentioning

confidence: 99%

Water Invasion Law and Water Invasion Risk Identification Method for Deep Sea Bottom-Water Gas Reservoir

Zhi

et al. 2022

Energies

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This study analyzes the water invasion characteristics and water encroachment of the deep sea bottom-water gas reservoir (LS17 field) in the South China Sea for the purpose of developing horizontal wells. Gas-producing profile tests and a three-dimensional (3D) water invasion simulation are used to produce a quantitative analysis of the bottom-water cresting influence factors. On this basis, we establish a suitable risk identification method for the water influx of a deep bottom-water reservoir. The results show that: (1) During the development of a bottom-water gas reservoir, the water ridging is affected by reservoir heterogeneity, production system and heel–toe effect of a horizontal wellbore, and reservoir heterogeneity is the main influencing factor; (2) the horizontal–vertical ratio of the well area determines whether the gas well productivity will be affected by the risk of water invasion. The stronger the reservoir heterogeneity, the smaller the safety limit value of the horizontal–vertical ratio; (3) when the permeability differential increases gradually, the safety limit value of the transverse longitudinal ratio decreases in turn; (4) based on the relationship curve between permeability level difference and the safety limit value of the horizontal–vertical ratio in the well area, the horizontal–vertical ratio of the N1H well is far greater than the safety limit value. The well is at high risk of water invasion and should be developed by water control. In order to improve deep seabed water and gas reservoirs, water control development should be carried out in well areas with sufficient water energy and high water invasion risk. The water invasion characteristics of bottom-water gas reservoirs under different water control technologies (such as variable density screen technology, filling water blocking, breathable coated gravel technology, etc.) and production systems (periodic gas production technology) should be studied. The research results can not only judge the water invasion risk of deep seabed water and gas reservoirs under different permeability levels and gas production rates but also provide a reference for water control development of offshore and onshore bottom-water and gas reservoirs.

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Water invasion and remaining gas distribution in carbonate gas reservoirs using core displacement and NMR

Cited by 11 publications

References 25 publications

Physical Simulation Experimental Technology and Mechanism of Water Invasion in Fractured-Porous Gas Reservoir: A Review

Physical Simulation Experimental Technology and Mechanism of Water Invasion in Fractured-Porous Gas Reservoir: A Review

Residual Oil Distribution Pattern in a Fault-Solution Carbonate Reservoir and Countermeasures to Improve Oil Development Effectiveness

Water Invasion Law and Water Invasion Risk Identification Method for Deep Sea Bottom-Water Gas Reservoir

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