Stress-Dependent In Situ Gas Permeability in the Eagle Ford Shale

Bhandari, A. R.; Flemings, Peter B.; Hofmann, Ronny; Polito, P. J.

doi:10.1007/s11242-018-1021-6

Cited by 19 publications

(4 citation statements)

References 34 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The exponential nature of the decrease in volumetric permeability of the Clashach sandstone samples (composed of 90% of quartz and 10% of feldspar) depending on the deformation and effective compressional pressure was revealed in [7]. An exponential dependence of permeability on effective rock pressure was also obtained in other previous experimental works [8][9][10][11][12][13].…”

Section: Introductionsupporting

confidence: 61%

A Model of Reservoir Permeability Evolution during Oil Production

2021

View full text Add to dashboard Cite

In this paper, we present a mathematical model to predict the evolution of rock permeability depending on effective pressure during oil production. The model is based on the use of the results of well testing data from wells operating in the oil fields of the Perm–Solikamsk region in the north of the Volgo Ural oil and gas province. Dependences of the change in flow characteristics in the reservoir on the effective pressure were established. We performed a comparative assessment using permeability and effective pressure data that were normalized to dimensionless forms of k/ko and P/Po. The factors and their influence on the nature of the change in permeability from the reservoir pressure were determined. Depending on the type of rock, its composition, initial permeability, and bedding conditions, we determined the limits of variation of the constants in empirical equations describing the change in the permeability of rocks from the effective pressure. The mathematical model we developed enables the prediction of the change in permeability of rocks during oil production from reservoirs on the basis of reservoir properties such as initial permeability, initial reservoir pressure, average bedding depth, net-to-gross ratio, and initial effective rock pressure.

show abstract

Section: Introductionsupporting

confidence: 61%

A Model of Reservoir Permeability Evolution during Oil Production

2021

View full text Add to dashboard Cite

show abstract

“…Figure shows the distribution of wells in the field, where eight horizontal wells were completed in the Eagle Ford between 2011 and 2013, as shown by the black line in Figure . Similar to the Bakken, the Eagle Ford formation has an extremely tight rock matrix, where the permeability is at a nano-darcy to micro-darcy level. − The crude oil produced from Eagle Ford shale is also volatile because of the high percentage of light components in the oil. , At this site, the oil production rate dropped nearly 90% in the first 5 years of production, from a peak rate of 40,863 bbl/month (6.5 × 10 3 m 3 /month) (in August 2011) to 4500 bbl/month (0.715 × 10 3 m 3 /month) (in April 2016).…”

Section: Assessment Of Immiscible and Miscible Field Casesmentioning

confidence: 94%

Investigating Enhanced Oil Recovery in Unconventional Reservoirs Based on Field Case Review, Laboratory, and Simulation Studies

et al. 2022

View full text Add to dashboard Cite

Aimed at advancing gas injection enhanced oil recovery (EOR) technologies in unconventional reservoirs, this study comprised a series of activities to bridge the gap between the theoretical study and actual field applications. Twenty-four EOR pilot tests were collected from the major unconventional plays in North America to evaluate the performance of different EOR technologies. Fit-for-purpose experiments and simulations were performed to investigate the effects of injection rate and pressure on EOR performance, as well as to reveal the effectiveness of huff "n" puff (HnP) cycles in actual field operations. The selection of injection rate and pressure as key parameters for investigation was based on field observations and communications with oil and gas operators because these two parameters play critical roles in both facility design and overall cost for an EOR project. Results showed that miscible EOR with a high gas injection rate and pressure is required for field operations because the injected gas needs to penetrate and extract oil from the tight matrix. Experimental results indicated that there is a correlation between oil recovery and the logarithm of core volume for miscible EOR. Immiscible gas EOR could not yield a satisfactory EOR response in actual reservoirs because the injected gas tends to flow through fractures instead of penetrating the matrix to interact with oil. Results also showed that reaching minimum miscibility pressure (MMP) does not guarantee an optimum EOR operation in unconventional reservoirs. Pressure higher than MMP is preferred in field operations. When designed properly, up to a tenfold oil production rate boost is achievable in field applications within a short period. However, such a high-performance operation is only effective in the first several HnP cycles due to the limited gas penetration depth into the rock matrix.

show abstract

“…The simplified exponential dependence of the porous media permeability on the effective pressure, established by the experimental studies [34][35][36][37][38][39]68,69], has the following form:…”

Section: Porous Rocksmentioning

confidence: 99%

Effect of Effective Pressure on the Permeability of Rocks Based on Well Testing Results

et al. 2021

View full text Add to dashboard Cite

During the development of oil and gas fields, the permeability of the reservoirs decreases due to a decrease in reservoir pressure and an increase in effective pressure, as a result of which significant reserves of oil and gas remain in the reservoir. To predict the rate of decrease in oil production rates during field development and to respond quickly, it is necessary to know the law of permeability decrease with an increase in effective pressure. Existing methods for describing the change in the permeability of rocks were analyzed in the paper. Numerical analysis of the results of core studies from previously published papers and the results of field well testing on the examples of the north Perm region oil fields showed that in both cases, regardless of the type of rock and the type of reservoir, the change in permeability can be described by the same equations (exponential and power-law). Obtained equations can be used to predict changes in the permeability of terrigenous reservoirs of the north Perm region oil fields. At the same time, according to the results of well testing, an intensive decrease in permeability is observed with an increase in effective pressure. Analysis of the nature of permeability changes using the Two-Part Hooke’s Model showed that significant irreversible deformations are currently taking place in the formations of the oil fields under consideration. Predicting the change in permeability from effective pressure can allow to optimize the development of oil deposits.

show abstract

Stress-Dependent In Situ Gas Permeability in the Eagle Ford Shale

Cited by 19 publications

References 34 publications

A Model of Reservoir Permeability Evolution during Oil Production

A Model of Reservoir Permeability Evolution during Oil Production

Investigating Enhanced Oil Recovery in Unconventional Reservoirs Based on Field Case Review, Laboratory, and Simulation Studies

Effect of Effective Pressure on the Permeability of Rocks Based on Well Testing Results

Contact Info

Product

Resources

About