Analysis of Pressure Tests Through the Use of Instantaneous Source Response Concepts

Cinco-Ley, Héber; Kuchuk, Fikri J.; Ayoub, Joseph A.; Samaniego-V., F.; Ayestaran, L.

doi:10.2118/15476-ms

“…The impulse derivative is calculated from ∆t 2 .d(dp w / ∆t). The concept was published originally by CincoLey et al 40 Pseudo-real gas potentials, m(p) or ψ, and pseudo times (∆t a ) would be used in the case of gas reservoirs. Given that in the impulse derivative there is a ∆t 2 rather than a ∆t, the impulse derivative log-log diagnostic cross-plot yields a slope of 2.0 during the wellbore storage period.…”

Section: Well Testingmentioning

confidence: 99%

State-of-the-Art of Tight Gas Sands Characterization and Production Technology

Aguilera¹,

Harding²

2007

Canadian International Petroleum Conference

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As part of the activities of the ConocoPhillips Chair in Tight Gas Engineering in the Chemical and PetroleumEngineering Department at the University of Calgary, a comprehensive literature review has been conducted that has led to our understanding of the current status on the study of tight gas sand formations. This paper presents the results of that work concentrating initially on Canadian and U.S. tight gas sands. Next, we will examine these types of formations throughout the world.The resource base of tight gas sands is estimated to be between 90 and 1500 trillion cubic feet in Canada. The resource base around the world has been estimated at some 7500 trillion cubic feet.The literature survey discussed in this paper is the basis for the mission-oriented research on tight gas reservoirs conducted at the University of Calgary. This research looks at refining the resource base and recoveries from tight gas in Canada and finding economic means of extracting as much of this gas as possible. The planned research program will be presented. It is expected that the research program will result in the delivery of highly qualified professionals, with significant knowledge of tight gas formations, needed by industry and research organizations. In addition, it is likely that the research results will prove to be of value in other parts of the world, and will be exportable, creating business opportunities for Canadian companies. Evaluating the current status of geologic models, reservoir characterization, recovery and production technologies currently available for these types of formations is the first step in the effort to reach the final goal: finding economic means of producing as much of this gas as possible.

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“…Fenske 11 showed that the pressure behavior for a well that was flowed for a short period of time would match the slug test type curves. In addition, numerous authors [12][13][14][15] have shown that the fluid withdrawal can be considered to be an instantaneous source if the well is produced for a short period of time as compared to the shut-in time, This assumption has led to the development of impulse and slug testing for determination of permeability.…”

Section: Spe 90865mentioning

confidence: 99%

“…Evaluation of this flow regime, allows for the determination of reservoir transmissibility, flow capacity, and reservoir permeability. The Impulse-Fracture Iinjection Test is similar to more conventional well test methods, such as the slug test, closed chamber DST, and impulse test [26][27][28][29][30][31][32][33][34][35] . In these tests, a small volume of fluid is injected or produced from the reservoir to create a pressure perturbation that is evaluated to determine the reservoir flow properties.…”

Section: Spe 90865mentioning

confidence: 99%

Application of After-Closure Analysis Techniques to Determine Permeability in Tight Formation Gas Reservoirs

Britt

¹

,

Jones

²

,

Heidt

³

et al. 2004

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe primary objective of hydraulic fracturing is to create a propped fracture with sufficient conductivity and length to maximize or at least optimize well performance. In permeable reservoirs where transient flow is short lived, a fracture with a Dimensionless Fracture Capacity, F CD , of 2 is required to meet the design objective. In low permeability formations where transient flow can be extensive and where fracture fluid cleanup requires additional conductivity, an F CD in excess of 10 is desired. As a result, reservoir permeability becomes/is a key fracture design and analysis parameter. In higher permeability applications, permeability is determined simply, inexpensively, and routinely through conventional well testing techniques. Conventional well testing in tight formation gas reservoirs has not been proven as effective, can be expensive (cost of lengthy tests and production deferment), and is quite simply not routinely utilized. These reservoirs are often non productive without fracture stimulation and post fracture stimulation testing requires extensive shut-in time as the time to pseudo radial flow is proportional to the square of the fracture half-length. As a result, the development and routine use of any technique to determine permeability in these tight formation gas reservoirs has great value.In addition, without adequate well testing techniques and capabilities in tight gas reservoirs, the engineer is left with the use of log derived values of permeability which can often overstate in-situ permeability by factors of five to ten. Determination of in-situ permeability not only aids the well completion and stimulation but can be used to calibrate the log and core derived estimates of permeability improving performance predictions and field development. Prior papers have developed the use of After Closure Analysis techniques in permeable reservoirs, this paper will show the application of this technique to several tight gas formations in North America.This paper will demonstrate the following: 1) The effective application of this technique in tight gas formations in the U.S. and Canada, 2) Develop a cost effective and operationally simple means of collecting and analyzing the data, 3) Compare and contrast the technique to other methods of determining permeability in tight formation gas reservoirs, such as impulse, Perforation Inflow Diagnostic (PID), Closed Chamber Drill-Stem Tests (CCDST), post-frac build-up, production decline analysis, Modular Dynamic Formation Tester (MDT). 4) Show the application and value of calibrating log and core-derived permeability with in-situ measurements for improved well performance predictions.

show abstract

“…Evaluation of this flow regime, allows for the determination of reservoir transmissibility, flow capacity, and reservoir permeability. The Impulse-Fracture Iinjection Test is similar to more conventional well test methods, such as the slug test, closed chamber DST, and impulse test [26][27][28][29][30][31][32][33][34][35] . In these tests, a small volume of fluid is injected or produced from the reservoir to create a pressure perturbation that is evaluated to determine the reservoir flow properties.…”

Section: Spe 90865mentioning

confidence: 99%

Application of After-Closure Analysis Techniques to Determine Permeability in Tight Formation Gas Reservoirs

Britt¹,

Jones²,

Heidt³

et al. 2004

Proceedings of SPE Annual Technical Conference and Exhibition

0

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe primary objective of hydraulic fracturing is to create a propped fracture with sufficient conductivity and length to maximize or at least optimize well performance. In permeable reservoirs where transient flow is short lived, a fracture with a Dimensionless Fracture Capacity, F CD , of 2 is required to meet the design objective. In low permeability formations where transient flow can be extensive and where fracture fluid cleanup requires additional conductivity, an F CD in excess of 10 is desired. As a result, reservoir permeability becomes/is a key fracture design and analysis parameter. In higher permeability applications, permeability is determined simply, inexpensively, and routinely through conventional well testing techniques. Conventional well testing in tight formation gas reservoirs has not been proven as effective, can be expensive (cost of lengthy tests and production deferment), and is quite simply not routinely utilized. These reservoirs are often non productive without fracture stimulation and post fracture stimulation testing requires extensive shut-in time as the time to pseudo radial flow is proportional to the square of the fracture half-length. As a result, the development and routine use of any technique to determine permeability in these tight formation gas reservoirs has great value.In addition, without adequate well testing techniques and capabilities in tight gas reservoirs, the engineer is left with the use of log derived values of permeability which can often overstate in-situ permeability by factors of five to ten. Determination of in-situ permeability not only aids the well completion and stimulation but can be used to calibrate the log and core derived estimates of permeability improving performance predictions and field development. Prior papers have developed the use of After Closure Analysis techniques in permeable reservoirs, this paper will show the application of this technique to several tight gas formations in North America.This paper will demonstrate the following: 1) The effective application of this technique in tight gas formations in the U.S. and Canada, 2) Develop a cost effective and operationally simple means of collecting and analyzing the data, 3) Compare and contrast the technique to other methods of determining permeability in tight formation gas reservoirs, such as impulse, Perforation Inflow Diagnostic (PID), Closed Chamber Drill-Stem Tests (CCDST), post-frac build-up, production decline analysis, Modular Dynamic Formation Tester (MDT). 4) Show the application and value of calibrating log and core-derived permeability with in-situ measurements for improved well performance predictions.

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Analysis of Pressure Tests Through the Use of Instantaneous Source Response Concepts

Cited by 44 publications

References 26 publications

State-of-the-Art of Tight Gas Sands Characterization and Production Technology

State-of-the-Art of Tight Gas Sands Characterization and Production Technology

Application of After-Closure Analysis Techniques to Determine Permeability in Tight Formation Gas Reservoirs

Application of After-Closure Analysis Techniques to Determine Permeability in Tight Formation Gas Reservoirs

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