Layer | Fill | Outline |
---|
Map layers
Theme | Visible | Selectable | Appearance | Zoom Range (now: 0) |
---|
Fill | Stroke |
---|---|
Collaborating Authors
Results
This paper was prepared for the 47th Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in San, Antonio, Tex., Oct. 8–11, 1972 Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon requested to the Editor of the appropriate journal, provided agreement to give proper credit is made. provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers Office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines. Abstract Object of this paper is to present a mathematical technique for reservoir classification. Four tools of time series analysis are employed: autocorrelation, cross correlation, power spectrum, and filtering. Autocorrelation is used to classify the reservoir as random or stratified, cross correlation is used to determine if the strata can be correlated in the reservoir. Power spectrum is used to determine the frequency distribution of the time series and for picking the sampling interval for digitizing well picking the sampling interval for digitizing well logs or sampling cores. It is also used for determining the frequencies to be filtered out. The paper presents the theory, sample calculations and applies the data to a sandstone reservoir. The reservoir is stratified and the strata can be correlated from well to well. Introduction To calculate reserves and predict performance of a hydrocarbon bearing reservoir performance of a hydrocarbon bearing reservoir it is desirable to have information pertaining to the distribution of its rock pertaining to the distribution of its rock properties. It is necessary to know the porosity properties. It is necessary to know the porosity distribution to determine reserves and the variations of permeability to calculate the flow rates. With the increased use of numerical simulations to predict reservoir performance it is necessary to develop better performance it is necessary to develop better methods of determining the spatial variations of rock properties. There are three generally accepted ways of sampling a reservoir to determine these properties: well logging coring, and flow tests. In well logging and coring data is obtained at points which can be assigned a depth within a well. Usually flow tests give average properties of the well's drainage volume. From an engineering point of view, reservoirs can be classified in three ways: random, correlated strata, and non-correlated strata. The rock properties at a point in a random reservoir do not depend on the properties within the vertical or horizontal properties within the vertical or horizontal neighborhood of that point. In a correlated stratified reservoir the rock properties at a point are dependent on the rock properties point are dependent on the rock properties within a vertical and horizontal neighborhood of that point.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.54)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Deep Basin > Pembina Field > Viking Formation (0.98)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Deep Basin > Pembina Field > Cardium Formation (0.98)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Deep Basin > Cardium Field > Cardium Formation (0.98)
American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc. This paper was prepared for the 46th Annual Fall Meeting of the Society of Petroleum Engineers of AIME, held in New Orleans, Oct. 3–6, 1971. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal, provided agreement to give proper credit is made. provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines. Abstract Solutions to the equations describing flow in porous media under sinusoidal pressure conditions are available in the pressure conditions are available in the literature. Very little use has been made of this theory and the experimental applications reported have dealt with gases and no flow through the media. Frequency response data from sinusoidal pressure experiments using liquids can be pressure experiments using liquids can be used to characterize the porous media and fluid properties. The lack of this type of data is probably due to the difficulty of generating the sinusoidal disturbances having sufficient frequency range and amplitude. Measurements were made using a synthetic oil in an unconsolidated medium. Equipment was designed to generate pressure sine wave whose upper frequency limit was in excess of 1,000 rad./sec. The core was equipped with high speed pressure transducers at various positions along the medium which measured the positions along the medium which measured the pressure response at a known flow rate. pressure response at a known flow rate. The experiments were designed to study the effect of pressure amplitude and frequency on the response of the system. Comparison of the theory and these experiments indicates that there are definite frequency limits which may be used if the equations are to adequately describe the data. As the frequency and or permeability increases, the inertial terms become important. This study shows that practical use can be made of existing theory to increase our ability to describe the flow of fluids in porous media. porous media Introduction The measurement of pressure transient responses is one of the few methods available for the reservoir to communicate its rock and fluid properties to an observer. Frequency response methods have been used by several investigators to determine rock and fluid properties. Experimental studies have been reported which used sinusoidal pressure inputs in gas filled porous systems with storage pores. Other porous systems with storage pores. Other investigators have used pluse testing methods to determine reservoir properties. Several methods have been proposed for describing the behavior of pressure transients in porous media.
- Research Report > New Finding (0.88)
- Research Report > Experimental Study (0.74)