Transient Pressure Analysis of Horizontal Wells in a Multi-Boundary System

Rbeawi, Salam Jabbar Hussain Al; Tiab, Djebbar

doi:10.2118/142316-ms

Cited by 14 publications

(5 citation statements)

References 21 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Algeria (Rinaldi et al, 2014). Our model is a 2D cross section perpendicular to the well, so the pseudo-radial flow that develops in the long-term (Al Rbeawi and Tiab, 2013;Sheng, 2014) cannot be modeled. Despite this limitation, simulation results show that the proposed methodology can be successfully applied to detect and locate low-permeability faults both for water and CO 2 injection.…”

Section: Discussionmentioning

confidence: 99%

A methodology to detect and locate low-permeability faults to reduce the risk of inducing seismicity of fluid injection operations in deep saline formations

Vilarrasa

Bustarret

Laloui

et al. 2017

International Journal of Greenhouse Gas Control

View full text Add to dashboard Cite

Fluid injection in the subsurface has significantly increased over the last decades. Since fluid injection causes pressure buildup, reducing effective stresses, shear failure conditions may eventually occur, inducing microseismic and seismic events. Anticipating felt induced earthquakes that may be triggered in undetected faults is crucial for the success of fluid injection projects. We propose a methodology to detect and locate such low-permeability faults to reduce the risk of inducing felt seismic events. The methodology consists in using diagnostic plots to identify the divergence time between the logarithmic derivative of overpressure evolution measured in the field and the one that would correspond to an aquifer including the previously identified heterogeneities. We apply the proposed methodology to water and CO 2 injection through a horizontal well in a confined aquifer that has faults parallel to the well. We numerically obtain type curves that allow locating low-permeability faults once the divergence time is determined from the logarithmic derivative of overpressure for both water and CO 2 injection. Furthermore, we illustrate how to apply the methodology to detect multiple low-permeability faults. To perform a proper pressure management based on fault stability analysis to minimize the risk of inducing felt seismic events, the proposed methodology should be complemented with other multidisciplinary tools. This methodology can be extended to other geological settings and be used in several fluid injection applications.

show abstract

Section: Discussionmentioning

confidence: 99%

A methodology to detect and locate low-permeability faults to reduce the risk of inducing seismicity of fluid injection operations in deep saline formations

Vilarrasa

Bustarret

Laloui

et al. 2017

International Journal of Greenhouse Gas Control

View full text Add to dashboard Cite

show abstract

“…Therefore, as flow progresses beyond the horizontal wellbore and reaches the upper and lower boundaries, intermediate-time linear flow is generated. This flow period which is a transition between the vertical radial flow and the horizontal radial flow (pseudoradial or late time radial flow [7]), is predominant when the well length is sufficiently long compared to the formation thickness. The dimensionless pressure for this regime designated as PD2 is represented by the second part of eqn.…”

Section: Early Time Linear Flowmentioning

confidence: 99%

Pressure behaviour of a horizontal well sandwiched between two parallel sealing faults

Ogbamikhumi¹,

Adewole²

2020

Nig. J. Tech.

View full text Add to dashboard Cite

Generally, reservoir fluid flow is governed by diffusivity equation and solution to this equation helps to investigate pressure behaviour under certain reservoir and wellbore boundary conditions. In this paper however, the analytical solution method of Green and Source function is deployed to determine the performance of a horizontal well located between two parallel sealing faults, assuming simple rectangular reservoir geometry. Also, the dimensionless pressure and derivative approach is applied for all computations as it prevents the problem of unit conversions, reduces longer expressions and it helps to handle numerical values. The pressure expression derived from this work reveals that a maximum of two flow periods occur for the stated reservoir model. It was found out that an inverse relationship exists between dimensionless pressure and dimensionless length while pressure increased with thickness. Also high vertical permeability shortens the effect of the early radial flow period experienced by the horizontal well, thereby increasing productivity index. Finally, it was discovered that increased perforation length reduces the production potential of the horizontal well. Keywords: Dimensionless pressure, pressure derivatives, heterogeneity, pressure performance, reservoir and wellbore characterization.

show abstract

“…Estimation of distance from vertical wells to multiple boundaries without type-curve matching was presented by Ispas and Tiab (1999) and Jongkittinarukorn and Tiab (1996a). Jongkittinarukorn and Tiab (1996b) and Al Rbeawi and Tiab (2011b) extended TDS technique for horizontal wells in closed-boundary systems and multi-boundary systems, respectively. Escobar et al (2014j) studied pressure behavior in wedge and T-shaped reservoirs.…”

Section: State-of-the-art On Tds Techniquementioning

confidence: 99%

The power of TDS technique for well test interpretation: a short review

Escobar

Jongkittnarukorn

Hernández

2018

J Petrol Explor Prod Technol

View full text Add to dashboard Cite

Either pressure-transient analysis or rate-transient analysis can be interpreted by four methods: (1) conventional straight-line analysis, (2) type-curve matching procedure, (3) ACMM (automatic computer modeling matching), and (4) TDS (Tiab's direct synthesis) technique. The first three methods have serious drawbacks and are commonly misused by engineers. It does not mean they are useless since they provide good results if used properly. For example, combination of (4), (1), and (3) are strongly recommended by the authors since type-curve matching are tedious and use trial-and-error procedures. ACMM is not only the most used method, but also the most risky methodology since the non-linear regression analysis used to match the pressure test with the model output leads to multiple solutions (none uniqueness of the solution). Moreover, some engineers employ it as an inverse problem when pretending to define the model by matching the data with any model. For those who do not know the way, any transportation means is good for. This is a very wrong alternative since engineers must choose the reservoir model and the ACMM helps to find out the solution. Type-curve matching is not only risky, but tedious and it fails to provide accurate results in short tests. Conventional analysis has no way of verification and some engineers confuse the flow regimes and draw the straight line on the wrong region leading to wrong interpretations. TDS technique may be the panacea to the above-mentioned problems since it uses direct analytical solutions with information coming from characteristic points found on the pressure and pressure derivative vs. time log-log plot on which the interpreter can better define flow regimes and verify results from different sources. In this paper we demonstrate the practicability and accuracy of TDS technique with some detailed examples and results are quite well. The intention of this paper is to encourage people the use of TDS technique and provide a state-of-the-art of it. Although not mentioned, TDS technique has been used by common well test interpretation software. The power of TDS is not only based upon the accuracy and capability verification, but also the possibility of artificially created non-existing flow regimes to further estimate/verify reservoir parameters. This means the best and only accurate option for short pressure test interpretations is TDS technique. Then, an engineer is welcome to use the output results with ACMM to obtain an accurate matching.

show abstract

Transient Pressure Analysis of Horizontal Wells in a Multi-Boundary System

Cited by 14 publications

References 21 publications

A methodology to detect and locate low-permeability faults to reduce the risk of inducing seismicity of fluid injection operations in deep saline formations

A methodology to detect and locate low-permeability faults to reduce the risk of inducing seismicity of fluid injection operations in deep saline formations

Pressure behaviour of a horizontal well sandwiched between two parallel sealing faults

The power of TDS technique for well test interpretation: a short review

Contact Info

Product

Resources

About