A new analytical method based on pressure transient analysis to estimate carbon storage capacity of depleted shales: A case study

Chen, Zhiming; Li, Xinwei; Zhao, Xin; Feng, Xiaoxu; Zang, Jiachen; Li-zhong, HE

doi:10.1016/j.ijggc.2015.07.030

Cited by 46 publications

(21 citation statements)

References 43 publications

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“…In this section, type curves of SHS flow in IT and annuli are obtained and discussed in detail (Huang et al 2017(Huang et al , 2018a(Huang et al , 2018bFeng et al 2018;Sun et al 2017k, 2017l, 2018bZhang et al 2017aZhang et al , 2017bChen et al 2015Chen et al , 2016Chen et al , 2017. The injection pressure, temperature and mass flow rate at the heel point are 4.231 MPa, 566.6 K and 3 kg/s, respectively.…”

Section: Type Curve Analysismentioning

confidence: 99%

The heat and mass transfer characteristics of superheated steam in horizontal wells with toe-point injection technique

Sun

Yao

2018

J Petrol Explor Prod Technol

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Little efforts were done on the heat and mass transfer characteristics of superheated steam (SHS) flow in the horizontal wellbores. In this paper, a novel numerical model is presented to analyze the heat and mass transfer characteristics of SHS in horizontal wellbores with toe-point injection technique. Firstly, with consideration of heat exchange between inner tubing (IT) and annuli, a pipe flow model of SHS flow in IT and annuli is developed with energy and momentum balance equations. Secondly, coupled with the transient heat transfer model in oil layer, a comprehensive mathematical model for predicting distributions of pressure and temperature of SHS in IT and annuli is established. Then, type curves are obtained with numerical methods and iteration technique, and sensitivity analysis is conducted. The results show that (1). The decrease in SHS temperature in annuli caused by heat and mass transfer to oil layer is offset by heat absorbtion from SHS in IT. (2). SHS temperature in both IT and annuli increases with the increase in injection pressure. (3). IT heat loss rate decreases with the increases in injection pressure. (4). Increasing pressure can improve development effect. Keywords Superheated steam injection · Toe-point injection technique · Horizontal wellbores · Distributions of pressure and temperature · Heavy oil recovery List of symbols

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Section: Type Curve Analysismentioning

confidence: 99%

The heat and mass transfer characteristics of superheated steam in horizontal wells with toe-point injection technique

Sun

Yao

2018

J Petrol Explor Prod Technol

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“…where: As described by some previous researchers [21,[28][29][30], the CO2 flow within a hydraulic fracture system was assumed to be compressible and can be described as a 1D coordinate system ( Figure 5). CO2 flow within hydraulic fracture also obeys Darcy's law.…”

Section: Model Of Co 2 Flow In Sg Reservoir Systemmentioning

confidence: 99%

“…Due to the possible connection of the HFs system, it is a key point when dealing with the fluid transferring between those two fracture media. Zhou et al [30] and Chen et al [21] artificially determined the flow direction, while Jia et al [29] employed complex star-transformation to automatically determine the flow direction. In our work, the connecting HFs system is simple (sparse hydraulic fractures), therefore we artificially specify the flow direction and solve the issue of fluid transferring between those two fracture media.…”

Section: Hydraulic Fracture Systemmentioning

confidence: 99%

“…This outstanding contradiction urges us to determine whether multi-wells should be injected simultaneously or sequentially and how to inject them under different injection rates. As a result, this technology strongly challenges the previously effective methodology for estimating CO2 storage capacity using the semi-analytical pressure-buildup method mentioned above, which focuses on SMFHWs without pressure MWPI [21,22]. Therefore, finding a methodology to optimize the injection strategy of the MWPs scheme to maximize CO2 storage capacity is a necessity.…”

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confidence: 99%

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CO2 Storage Capacity for Multi-Well Pads Scheme in Depleted Shale Gas Reservoirs

et al. 2017

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As a promising technology to improve shale gas (SG) recovery and CO 2 storage capacity, the multi-well pads (MWPs) scheme has gained more and more attention. The semi-analytical pressure-buildup method has been used to estimate CO 2 storage capacity. It focuses on single multi-fractured horizontal wells (SMFHWs) and does not consider multi-well pressure interference (MWPI) induced by the MWPs scheme. This severely limits the application of this method as incidences of multi-well pressure interference have been widely reported. This paper proposed a new methodology to optimize the injection strategy of the MWPs scheme and maximize CO 2 storage capacity. The new method implements numerical discretization, the superposition theory, Gauss elimination, and the Stehfest numerical algorithm to obtain pressure-buildup solutions for the MWPs scheme. The solution by the new method was validated with numerical simulation and pressure-buildup curves were generated to identify MWPI. Using the new method, we observed that the fracture number and fracture half-length have a positive influence on CO 2 storage capacity. Both can be approximately related to the CO 2 storage capacity by a linear correlation. For a given injection pressure, there is an optimal fracture number; the bigger the limited injection pressure, the smaller the optimal fracture number. Stress sensitivity has positive influences on CO 2 storage capacity, thus extending the injection period would improve CO 2 storage capacity. This work gains some insights into the CO 2 storage capacity of the MWPs scheme in depleted SG reservoirs, and provides considerable guidance on injection strategies to maximize CO 2 storage capacity in depleted SG reservoirs.

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“…Geological storage of CO2 is one of the most promising ways to mitigate global warming and climate change [1]. Shale gas reservoirs, which are characterized as having ultra low permeability and high storage potential, are suitable for CO2 sequestration [2][3][4].…”

Section: Introductionmentioning

confidence: 99%

Experimental Investigation of Mechanical Properties of Black Shales after CO<sub>2</sub>-Water-Rock Interaction

Lyu¹,

Ranjith²,

Long³

et al. 2016

Preprint

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Abstract:The effects of CO2-water-rock interactions on the mechanical properties of shale are essential for estimating the possibility of sequestrating CO2 in shale reservoirs. In this study, uniaxial compressive strength (UCS) tests together with an acoustic emission (AE) system and SEM and EDS analysis were performed to investigate the mechanical properties and microstructural changes of black shales with different saturation times (10 days, 20 days and 30 days) in water dissoluted with gaseous/super-critical CO2. According to the experimental results, the values of UCS, Young's modulus and brittleness index decrease gradually with increasing saturation time in water with gaseous/super-critical CO2. Compared to samples without saturation, 30-day saturation causes reductions of 56.43% in UCS and 54.21% in Young's modulus for gaseous saturated samples, and 66.05% in UCS and 56.32% in Young's modulus for super-critical saturated samples, respectively. The brittleness index also decreases drastically from 84.3% for samples without saturation to 50.9% for samples saturated in water with gaseous CO2, to 47.9% for samples saturated in water with super-critical carbon dioxide (SC-CO2). SC-CO2 causes a greater reduction of shale's mechanical properties. The crack propagation results obtained from the AE system show that longer saturation time produces higher peak cumulative AE energy. SEM images show that many pores occur when shale samples are saturated in water with gaseous /super-critical CO2. The EDS results show that CO2-water-rock interactions increase the percentages of C and Fe and decrease the percentages of Al and K on the surface of saturated samples when compared to samples without saturation.

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A new analytical method based on pressure transient analysis to estimate carbon storage capacity of depleted shales: A case study

Cited by 46 publications

References 43 publications

The heat and mass transfer characteristics of superheated steam in horizontal wells with toe-point injection technique

The heat and mass transfer characteristics of superheated steam in horizontal wells with toe-point injection technique

CO2 Storage Capacity for Multi-Well Pads Scheme in Depleted Shale Gas Reservoirs

Experimental Investigation of Mechanical Properties of Black Shales after CO<sub>2</sub>-Water-Rock Interaction

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