Abstract:High and efficient deliverability of stimulated reservoir volume through a hydraulic fracturing treatment relies on three segments: fluid flow from matrix to the interface between fracture and matrix media, fluid-rock interaction at the fracture-matrix interface, and conductivity of fracture network. Thus, fluids and salt exchange between matrix and fracture network are critical and worth detailed investigation. Moreover, matrix imbibition as an important EOR mechanism has been extensively studied but the focu… Show more
“…The incorporation of both mechanisms is critical in properly modeling water dynamics in both fracture ,− and matrix imbibition . Li et al integrate the two mechanisms to develop a one-dimensional imbibition model for shale using samples from the Horn River basin …”
Spontaneous imbibition
is one of the mechanisms proposed to reveal
the fate of fluids used during fracturing operations in shale reservoirs.
However, the influence of salinity and mineralogy on the imbibition
kinetics is not yet well understood. We performed imbibition experiments
on samples collected from Woodford and Caney shale outcrops with slick
water having salinities up to 15 wt % KCl. The impact of salinity
on the imbibition rate and capacity shows a different trend for samples
of varying mineralogy. A correlation between the carbonate/clay ratio
and the imbibition rate is observed. This ratio and the illite content
were linked to be factors affecting the impact of salinity on imbibition.
This correlation suggests a maximum volume of imbibition at a ratio
of 1.5. The impact of salinity on the formation strength seems to
correlate with the amount of siderite and anhydrite present in the
rock. It is worth noting that the swelling of the expansive clay minerals
could mask the imbibition signature of the samples, where the apparent
weight is used to estimate the liquid uptake. This is mainly apparent
in the later stages when the bulk volume expansion can outweigh the
liquid uptake; however, this effect does not reach the level of impacting
the trends and correlations observed in this study.
“…The incorporation of both mechanisms is critical in properly modeling water dynamics in both fracture ,− and matrix imbibition . Li et al integrate the two mechanisms to develop a one-dimensional imbibition model for shale using samples from the Horn River basin …”
Spontaneous imbibition
is one of the mechanisms proposed to reveal
the fate of fluids used during fracturing operations in shale reservoirs.
However, the influence of salinity and mineralogy on the imbibition
kinetics is not yet well understood. We performed imbibition experiments
on samples collected from Woodford and Caney shale outcrops with slick
water having salinities up to 15 wt % KCl. The impact of salinity
on the imbibition rate and capacity shows a different trend for samples
of varying mineralogy. A correlation between the carbonate/clay ratio
and the imbibition rate is observed. This ratio and the illite content
were linked to be factors affecting the impact of salinity on imbibition.
This correlation suggests a maximum volume of imbibition at a ratio
of 1.5. The impact of salinity on the formation strength seems to
correlate with the amount of siderite and anhydrite present in the
rock. It is worth noting that the swelling of the expansive clay minerals
could mask the imbibition signature of the samples, where the apparent
weight is used to estimate the liquid uptake. This is mainly apparent
in the later stages when the bulk volume expansion can outweigh the
liquid uptake; however, this effect does not reach the level of impacting
the trends and correlations observed in this study.
“…Neuzil and Provost [89] observed the anomalous fluid pressure in a subsurface when they performed osmosis measurements on moderately compacted high clay content Pierre shale. This can be illustrated by electric double layer (EDL) theory [90]. Clay particles are naturally and commonly negatively charged.…”
In petroleum engineering, imbibition is one of the most important elements for the hydraulic fracturing and water flooding processes, when extraneous fluids are introduced to the reservoir. However, in unconventional shale formations, osmosis has been often overlooked, but it can influence the imbibition process between the working fluid and the contacting formation rocks. The main objective of this study is to understand effects of fluid–rock interactions for osmosis-associated imbibition in unconventional formations. This paper summarizes previous studies on imbibition in unconventional formations, including shale, tight carbonate, and tight sandstone formations. Various key factors and their influence on the imbibition processes are discussed. Then, the causes and role of osmotic forces in fluid imbibition processes are summarized based on previous and recent field observations and laboratory measurements. Moreover, some numerical simulation approaches to model the osmosis-associated imbibition are summarized and compared. Finally, a discussion on the practical implications and field observations of osmosis-associated imbibition is included.
“…Measurements were repeated three times for each experiment, at room temperature. For measurement of the contact angle in the porous rock, the disks were first polished with six different grades of sandpaper to minimize the roughness effect (Al-Shaikh and Mahadevan 2016; Li et al 2016). The standard deviation of the measurement was in the range of 0.13-0.21, which indicates that the measured contact angles were relatively consistent.…”
When low-salinity water containing sulfate ions is injected into carbonate reservoirs, rock dissolution and in situ precipitation occur, altering rock permeability and wettability. Particularly, when barium ions are present in formation water, they react chemically with SO 2À 4 , and BaSO 4 is precipitated. These reactions can cause a serious impact on the efficiency of enhanced oil recovery (EOR). Therefore, the main purpose of this study was to identify EOR efficiency induced by lowsalinity waterflooding (LSWF) when Ba 2? is present in carbonate reservoirs. From the experimental results, it was confirmed that the permeability calculated by the measured pressure difference was improved because of rock dissolution predominating over in situ precipitation for the case of low Ba 2? concentrations. In the analysis of wettability alteration through the measurements of relative permeabilities before and after LSWF, the higher Ba 2? concentration case consumed more SO 2À 4 in precipitating the BaSO 4 , resulting in weaker wettability alteration due to the reduction of sulfate activity. These phenomena ultimately influenced EOR efficiency, i.e., the oil recovery was greater for the lower Ba 2? concentration.
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