Decline curve analysis for multiple-fractured horizontal wells in tight oil reservoirs

Xu, Guohan; Yin, Hongjun; Yuan, Hongfei; Xing, Cuiqiao

doi:10.46690/ager.2020.03.07

Cited by 19 publications

(8 citation statements)

References 21 publications

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“…www.nature.com/scientificreports/ Water invasion analysis. Currently, the main methods of water invasion degree identification can be divided into three main methods: the pressure drop curve method, the apparent geological reserves method and the water invasion volume coefficient method [30][31][32][33] . Using the water invasion volume coefficient method, the θ ∼ R curves of Group I were drawn; details are presented in Appendix A.…”

Section: Resultsmentioning

confidence: 99%

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Physical simulation for water invasion and water control optimization in water drive gas reservoirs

et al. 2021

Sci Rep

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The development of water drive gas reservoirs (WDGRs) with fractures or strong heterogeneity is severely influenced by water invasion. Accurately simulating the rules of water invasion and drainage gas recovery countermeasures in fractured WDGRs, thereby revealing the mechanism of water invasion and an appropriate development strategy, is important for formulating water management measures and enhancing the recovery of gas reservoirs. In this work, physical simulation methods were proposed to gain a better understanding of water invasion and to optimize the water control of fractured WDGRs. Five groups of experiments were designed and conducted to probe the impacts of the distance between the fractures and the gas well, the drainage position, the drainage timing and the aquifer size on the water invasion and production performance of a gas reservoir. The gas and water production and the internal pressure drop were monitored in real time during the experiments. Based on the above experimental works, a theoretical analysis was conducted to quantitatively evaluate the performance of the gas reservoir recovery via the gas well production performance, water invasion, dynamic pressure drop and residual gas and water distribution analysis. The results show that when the fracture scale was appropriate, a gas well drilled close to a fracture (Experiment 1-3) or a high-permeability formation could also produce gas and achieve drainage efficiently. The recovery factor of Experiment 1-3 reached 62.5%, which was 24.6% and 21.1% higher than those of Experiments 1-1 and 1-2, respectively, which had wells drilled in low-permeability areas. Draining water near an aquifer can effectively inhibit water invasion during the early stage of gas recovery. The setup in Experiment 2-1 effectively inhibited water invasion and avoided the formation of water-sealed volumes of gas to recover 30% more gas than recovered with that of Experiment 1-1 without drainage wells. A shorter distance between the drainage well and the aquifer increased the drainage capacity and decreased the gas production capacity, respectively (Well 2 at Point A vs Point B). A larger aquifer had a lower gas recovery, which reduced the economic benefit. For example, due to an infinitely large aquifer, the reserves in Experiment 4-1 were developed by a single well, the gas recovery was only 33.4%. These research results are expected to be beneficial for the preparation of development plans and the optimization of water control measures for WDGRs.

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Section: Resultsmentioning

confidence: 99%

“…Currently, the main methods of water invasion degree identification can be divided into three main methods: the pressure drop curve method, the apparent geological reserves method and the water invasion volume coefficient method 30 – 33 .…”

Section: Resultsmentioning

confidence: 99%

Physical simulation for water invasion and water control optimization in water drive gas reservoirs

et al. 2021

Sci Rep

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Section: Water Invasion Analysismentioning

confidence: 99%

Physical Simulation for Water Invasion and Water Control Optimization in Water Drive Gas Reservoirs

et al. 2021

Preprint

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The development of water drive gas reservoirs (WDGRs) with fractures or strong heterogeneity is severely influenced by water invasion. Accurately simulating the rules of water invasion and drainage gas recovery countermeasures in fractured WDGRs, thereby revealing the mechanism of water invasion and an appropriate development strategy, is important for formulating water management measures and enhancing the recovery of gas reservoirs. In this work, physical simulation methods were proposed to gain a better understanding of water invasion and to optimize the water control of fractured WDGRs. Five groups of experiments were designed and conducted to probe the impacts of the distance between the fractures and the gas well, the drainage position, the drainage timing and the aquifer size on the water invasion and production performance of a gas reservoir. The gas and water production and the internal pressure drop were monitored in real time during the experiments. Based on the above experimental works, a theoretical analysis was conducted to quantitatively evaluate the performance of the gas reservoir recovery via the gas well production performance, water invasion, dynamic pressure drop and residual gas and water distribution analysis. The results show that when the fracture scale was appropriate, a gas well drilled close to a fracture (Experiment 1–3) or a high-permeability formation could also produce gas and achieve drainage efficiently. The recovery factor of Experiment 1–3 reached 62.5%, which was 24.6% and 21.1% higher than those of Experiments 1–1 and 1–2, respectively, which had wells drilled in low-permeability areas. Draining water near an aquifer can effectively inhibit water invasion during the early stage of gas recovery. The setup in Experiment 2 − 1 effectively inhibited water invasion and avoided the formation of water-sealed volumes of gas to recover 30% more gas than recovered with that of Experiment 1–1 without drainage wells. A shorter distance between the drainage well and the aquifer increased the drainage capacity and decreased the gas production capacity, respectively (Well 2 at Point A vs Point B). A larger aquifer had a lower gas recovery, which reduced the economic benefit. For example, due to an infinitely large aquifer, the reserves in Experiment 4 − 1 were developed by a single well, the gas recovery was only 33.4%. These research results are expected to be beneficial for the preparation of development plans and the optimization of water control measures for WDGRs.

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“…Previous studies have shown that the influence of fracture geometrical parameters, in particular the fracture scale, is substantial with respect to effective permeability and rock physical properties (de Dreuzy et al ., 2001; Tran et al ., 2006; Wang et al ., 2017; Ghasemi et al ., 2020). During reservoir production and shale gas fracturing, the effective hydraulic fracturing treatment is necessarily influenced by the distribution and geometry of the natural fracture system as well as by the present maximum horizontal stress (Gale et al ., 2007; Zhang et al ., 2019; Xu et al ., 2020). The injected hydrate raises the fluid pressure, which creates new fractures and causes the growth of existing fractures, thus providing improved permeability and enhancing the hydraulic fracturing treatment and reservoir production (Liu et al ,.…”

Section: Introductionmentioning

confidence: 99%

Observation and theoretical calibration of the fluid flow mechanism of artificial porous rocks with various size fractures

Ding

Wei

et al. 2021

Geophysical Prospecting

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Fractures usually spread over various scales and strongly influence velocity and anisotropy. We investigate elastic velocity and anisotropy in rocks with fractures of different sizes. Based on synthetic rocks with controlled fracture geometries, we create a set of rocks with fracture diameter of 2, 3 and 4 mm and the fracture thickness is 0.06 mm. P‐ and S‐wave velocities are measured at 0.1 MHz, while the rocks are saturated with water and air. For a fixed measurement frequency (0.1 MHz), velocities are higher in rocks with larger fractures, while anisotropy is higher in rocks with smaller fractures, even for the same fracture density. These phenomena are associated with the wave‐induced fluid flow process. Some novel effective medium theories are adopted to calibrate with the laboratory data and analyse the anisotropy affected by the fluid flow mechanism and fracture size. The results of our study demonstrate the significant effects of fracture scale on wave responses by effective medium theories in different ways. We suggest that these scale effects should be of considerable concern in some disciplines (e.g. shear wave splitting in earth's crust and hydraulic fracture monitoring with microseismic data). Considering the scale effects of fractures, the accuracy during these investigations would be improved.

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Decline curve analysis for multiple-fractured horizontal wells in tight oil reservoirs

Cited by 19 publications

References 21 publications

Physical simulation for water invasion and water control optimization in water drive gas reservoirs

Physical simulation for water invasion and water control optimization in water drive gas reservoirs

Physical Simulation for Water Invasion and Water Control Optimization in Water Drive Gas Reservoirs

Observation and theoretical calibration of the fluid flow mechanism of artificial porous rocks with various size fractures

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