EP3452698B1 - Estimation de pression de réservoir bidimensionnelle avec données de relevé de pression statique de fond de trou et modélisation de simulation intégrées - Google Patents

Estimation de pression de réservoir bidimensionnelle avec données de relevé de pression statique de fond de trou et modélisation de simulation intégrées Download PDF

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EP3452698B1
EP3452698B1 EP17722360.9A EP17722360A EP3452698B1 EP 3452698 B1 EP3452698 B1 EP 3452698B1 EP 17722360 A EP17722360 A EP 17722360A EP 3452698 B1 EP3452698 B1 EP 3452698B1
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reservoir
pressure
cells
wells
interest
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EP3452698A1 (fr
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Umar A. Al-Nahdi
Ali A. AL-TURKI
Badr M. Al-Harbi
Sami A. AL-NUAIM
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Saudi Arabian Oil Co
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Saudi Arabian Oil Co
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Priority claimed from US15/146,323 external-priority patent/US10571604B2/en
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure

Definitions

  • the present invention relates to determination or mapping of reservoir pressure over a region of interest in a subsurface reservoir with integration of static bottom-hole pressure survey data and simulation modeling.
  • underground hydrocarbon reservoirs typically includes development and analysis of computer simulation models of the reservoir.
  • These underground hydrocarbon reservoirs are typically complex rock formations which contain both a petroleum fluid mixture and water.
  • the reservoir fluid content usually exists in two or more fluid phases.
  • the petroleum mixture in reservoir fluids is produced by wells drilled into and completed in these rock formations.
  • a computer reservoir model with realistic geological features and properties, appropriate distribution of in-situ fluids, as well as initial pressure conditions of the fluids also help in forecasting the optimal future oil and gas recovery from hydrocarbon reservoirs.
  • Oil and gas companies have come to depend on such models as an important tool to enhance the ability to exploit a petroleum reserve.
  • the reservoir is simulated in a computer and runs are made of estimated production for a range of times over the projected life of the reservoir.
  • the reservoir is organized into a number of individual cells. Seismic data with increasing accuracy has permitted the cells to be on the order of 25 meters areal (x and y axis) intervals. For what are known as giant reservoirs, the number of cells is at least hundreds of millions, and reservoirs of what is known as giga-cell size (a billion cells or more) are encountered.
  • An example reservoir of the type for which production data are simulated over the expected reservoir life as illustrated by the model M ( Figure 1 ) is usually one which is known to those in the art as a giant reservoir.
  • a giant reservoir may be several miles in length, breadth and depth in its extent beneath the earth and might, for example, have a volume or size on the order of ninety-one billion square meters (three hundred billion cubic feet).
  • the reservoir is organized into a matrix which corresponds to the three dimensional extent of the reservoir and is composed of a number of contiguous 3-dimensional cells. It is common for a reservoir matrix to contain millions of cells to obtain as accurate an indication of reservoir conditions as feasible. Actual reservoir models may have several millions of such cells.
  • the actual number of wells may also be on the order of a thousand, with each well having a number of perforations into producing formations.
  • each well having a number of perforations into producing formations.
  • not all of the wells in a reservoir have what are known as permanent downhole pressure gauges in them to monitor reservoir at those locations. This however represents a pressure measurement at only one point in the huge volume of the reservoir.
  • the reservoir may have a substantial extent in terms of subsurface breadth, width and depth, leading to a very large number of cells in the model.
  • the data points are extremely scarce when compared to the reservoir volume.
  • SBHP static bottom-hole pressure
  • US2009276100 considered the closest prior art, describes systems, program product, and methods for providing real-time reservoir management of one or more reservoirs across one or more fields.
  • US2012179436 describes simulation of a subterranean reservoir where the pore space of media or formation rock is multimodal, and the media may have imbedded multiple scales of fracture networks.
  • US2015066373 describes three-dimensional reservoir pressure determination using real-time pressure data from downhole gauges.
  • US3303704 describes hydrodynamic exploration in variable density environments.
  • the present invention provides a new and improved computer implemented method of forming a two-dimensional pressure map with a data processing system of reservoir pressures in a region of interest in a subsurface hydrocarbon producing reservoir partitioned for modeling purposes into a reservoir model partitioned as an array of a grid of cells extending over the three dimensions of the reservoir, the reservoir having a plurality of wells with perforations for fluid passage from the reservoir into the wells, with selected ones of the wells having downhole pressure measurement systems installed therein, the array of a grid of cells of the reservoir model comprising well cells at the locations of the wells and reservoir cells at the remaining cells of the grid.
  • the computer processing receives pressure data from the wells based on measurements from the downhole pressure measurement systems, and performs simulated pressure calculations on a reservoir simulator in the data processing system for the cells in an array of well cells for an area of interest of the reservoir.
  • Well cells at an uppermost perforation of each of the wells are populated with assigned pressure values from the received pressure data.
  • Pressure values are propagated for the well cells of the wells below the uppermost perforations and for the reservoir cells of the area of interest to form a three-dimensional grid pressure array for the area of interest.
  • the three-dimensional grid pressure array is then collapsed or transformed to a two-dimensional layer of pressure values for the region of interest.
  • the two-dimensional layer of pressure values for the region of interest are assembled in memory of the data processing system and an output image map is formed of the two-dimensional layer of pressure values for the region of interest.
  • the present invention also provides a new and improved data processing system for forming a two-dimensional pressure map with a data processing system of reservoir pressures in a region of interest in a subsurface hydrocarbon producing reservoir partitioned for modeling purposes into a reservoir model partitioned as an array of a grid of cells extending over the three dimensions of the reservoir, the reservoir having a plurality of wells with perforations for fluid passage from the reservoir into the wells, with selected ones of the wells having downhole pressure measurement systems installed therein, the array of a grid of cells of the reservoir model comprising well cells at the locations of the wells and reservoir cells at the remaining cells of the grid.
  • the data processing system includes a processor which receives pressure data from the wells based on measurements from the downhole pressure measurement systems, and performs simulated pressure calculations on a reservoir simulator in the data processing system for the cells in an array of well cells for an area of interest of the reservoir.
  • the processor then populates well cells at an uppermost perforation of each of the wells with assigned pressure values from the received pressure data, and propagates pressure values for the well cells of the wells below the uppermost perforations and to the reservoir cells of the area of interest to form a three-dimensional grid pressure array for the area of interest.
  • the processor then reduces the three-dimensional grid pressure array to a two-dimensional layer of pressure values for the region of interest, and assembles in memory of the data processing system the measure of two-dimensional layer of pressure values of the region of interest.
  • the data processing system also includes a memory storing the two-dimensional layer of pressure values for the region of interest an output display forming a display of the two-dimensional layer of pressure values for the region of interest of the reservoir.
  • the present invention also provides a new and improved data storage device which has stored in a computer readable medium non-transitory computer operable instructions for causing a data processing system to form a two-dimensional pressure map with a data processing system of reservoir pressures in a region of interest in a subsurface hydrocarbon producing reservoir partitioned for modeling purposes into a reservoir model partitioned as an array of a grid of cells extending over the three dimensions of the reservoir.
  • the reservoir has a plurality of wells with perforations for fluid passage from the reservoir into the wells, with selected ones of the wells having downhole pressure measurement systems installed therein, the array of a grid of cells of the reservoir model comprising well cells at the locations of the wells and reservoir cells at the remaining cells of the grid.
  • the instructions stored in the data storage device cause the data processing system to receive pressure data from the wells based on measurements from the downhole pressure measurement systems, and perform simulated pressure calculations on a reservoir simulator in the data processing system for the cells in an array of well cells for an area of interest of the reservoir.
  • the instructions also cause the data processing system to populate well cells at an uppermost perforation of each of the wells with assigned pressure values from the received pressure data, and then propagate pressure values for the well cells of the wells below the uppermost perforations and to the reservoir cells of the area of interest to form a three-dimensional grid pressure array for the area of interest.
  • the instructions further cause the data processing system to reduce the three-dimensional grid pressure array to a two-dimensional layer of pressure values for the region of interest, and assemble in memory of the data processing system the two-dimensional layer of pressure values for the region of interest, then form an output image map of the two-dimensional layer of pressure values for the region of interest.
  • the letter M designates a simplified model of a portion of a subsurface hydrocarbon reservoir for which production results based on operating conditions and parameters are simulated over an estimated production life according to the present invention based on geological and fluid characterization information obtained for the cells of the reservoir. The results obtained are thus available and used for simulation of historical performance and for forecasting of production from the reservoir. Based on the results of such simulation, models such as those described and shown in U. S. Patent No. 7,526,418 are then formed and are available for evaluation and analysis. U. S. Patent No. 7,526,418 is owned by the assignee of the present invention.
  • the physical size of the reservoir may be several miles in length, breadth and depth in its extent beneath the earth and might, for example, have a volume or size on the order of ninety-one billion square meters (three hundred billion cubic feet).
  • the number of cells for a reservoir of this size is, for example, typically on the order of hundreds of millions.
  • the actual number of wells may also be on the order of a thousand, with each well having a number of perforations into producing formations.
  • a limited number of the wells in a reservoir have what are known as permanent downhole pressure gauges in them to monitor reservoir at those locations. This, however, represents a pressure measurement at only one point in the volume of the reservoir.
  • the reservoir may have a substantial extent in terms of subsurface breadth, width and depth, leading to a very large number of cells in the model.
  • the reservoir pressure data points are extremely scarce when compared to the reservoir volume.
  • Figure 2 illustrates an example placement of a group G of wells W from a portion of a large reservoir R of the type and size exemplified by the model M of Figure 1 .
  • the wells in the group G typically include production wells, injection wells and observation wells and are spaced over the extent of the reservoir.
  • certain ones of the wells W represented by the group G are provided with permanent downhole measurement systems 20, which are known as PDHMS.
  • the PDHMS 20 may, for example be of the type described in U. S. Patents Nos. 8,078,328 and 8,312,320 , commonly owned by the assignee of the present application.
  • the PDHMS 20 include surface units which receive reservoir and well data in real time from downhole sensors 22.
  • the downhole sensors 22 obtain data of interest, and for the purposes of the present invention the downhole sensors include downhole pressure and temperature sensors located in the wells W at selected depths and positions in the selected group G of wells among the much larger number of wells in the reservoir.
  • the downhole sensors 22 furnish the collected real-time pressure and temperature data from the wells W in which they are installed, and a supervisory control and data acquisition (SCADA) system with a host computer or data processing system D ( Figure 4 ) collects and organizes the collected data form the wells in the group G.
  • SCADA supervisory control and data acquisition
  • the PDHMS 20 also includes sensors to record production and injection data for the injection wells in the group G, which data is also collected and organized by the supervisory control and data acquisition.
  • a flow chart F displays a set of processor steps performed according to the methodology of the present invention in a data processing system D ( Figure 10 ) for three-dimensional reservoir pressure determination using real time pressure data from downhole gauges and reservoir simulation values determination to determine and form 2-dimensional isobaric pressure maps according to the present invention.
  • the flowchart F indicates the basic computer processing sequence of the present invention and the computation taking place in the data processing system D for the 3-dimensional pressure determination reservoir simulation and map formation according to the present invention.
  • Processing according to the flow chart F of Figure 3 is performed in conjunction with results of processing according to Applicant's co-pending, commonly owned U. S. Patent Application No. 14/014,658, filed August 30, 2013 , and in particular to the determination of an i-Reservoir calculated pressure P cal and the pressure gradients between cells of the reservoir model.
  • certain input parameters are provided as indicated at step 30 by users interested in reservoir management according to the present invention.
  • the input parameters are identifications of each of the following: Field, Reservoir(s), Pressure Survey Data (SBHP), and Target Date for which a two dimensional reservoir pressure estimation map is to be formed.
  • step 32 input perforation and production/injection data obtained by the reservoir simulator R in the data processing system D are also provided and subjected to quality checking as shown at step 34.
  • the reservoir simulation model is thus updated with the latest perforations and production/injection data for the wells of interest in the reservoir or field.
  • step 36 pressure gradients between the reservoir model grid blocks or reservoir cells of the model M are determined according to the techniques of U. S. Patent Application No. 14/014,658 , mentioned above.
  • the gradients between grid blocks are indicative of pressure changes in the reservoir due to geological heterogeneity, fluid dynamics, model constrains, and production/injection activities.
  • step 38 the pressure gradients determined by reservoir simulator R as a result of step 36 are evaluated.
  • a perforation file of the reservoir data in the reservoir data is parsed and stored.
  • the perforation file is also sorted by depth for each well in the reservoir.
  • Pressure survey or SBHP survey data is also parsed and stored during step 38, as is needed data, which include samples of SBHP and of perforation data from the reservoir simulation model output. Inactive cells which are to be excluded from processing computation are then identified during step 38 and then discarded along with their data content.
  • step 39 pressure survey data obtained from the reservoir in the manner described above as illustrated schematically in Figure 2 is then used to determine reservoir pressure values at well top perforations of the wells 22 in the reservoir according to the techniques of U. S. Patent Application No. 14/014,658 , mentioned above. Then, in step 40, pressure values are propagated for each of the perforations of each of the wells 22.
  • step 40 there are three methods of performing step 40 for propagation of pressure values based on pressure survey data to be propagated to the perforations in the reservoir model and further to the reservoir models cells away from one or more of the wells. They are: an All Perforation Method as indicated schematically at 42 in Figure 4 ; a Single Perforation Column Method shown schematically at 44 in Figure 5 ; and an All-Perforation Column Method shown at 46 in Figure 6 .
  • the All Perforation processing 42 begins with step 48 where SBHP values are assigned to the first or uppermost perforation in a well.
  • measures from the simulation model of pressure gradient between the perforated cells are used to propagate pressure calculation successively from the first or uppermost cells to last lowest cells in the well.
  • All perforations thus used are control points used in step 52 to propagate pressure assignments to non-perforated cells according to suitable statistical methods as describe in U. S. Patent Application No. 14/014,658 .
  • a suitable such method is that known as Distance-Weighted Moving Average or DWMA.
  • FIG. 7A illustrates schematically lower performance of step 52, where pressure gradient measures for reservoir simulation are successively propagated from perforation 54 successively to lower perforations 58 and 60. Since inactive cells have, as described above, been excluded from processing, perforations 54, 58 and 60 are shown vertically adjacent each other in Figures 7A , 7B and 7C.
  • Figure 7C illustrates schematically the assignment of pressure values to non-perforated cells 62 according to Distance-Weighted Moving Average or DWMA methods, as will be described.
  • FIG. 8A illustrates schematically the Single-Perforation Column Method step 64 where average column pressure measures as shown at 72 are determined and a pressure correction factor is subtracted as indicated at 74 resulting in an i-Reservoir pressure as shown at 76 and 78 for different cells in a column 80.
  • Figure 8B illustrates schematically step 82 where the resultant i-Reservoir calculated pressure value P cal is determined for the cells 84 of the grid of the simulation model M.
  • the average column pressure is the ( P SBHP ).
  • each of the i perforations of a well are considered for calculating pressure along the well and away from it.
  • the perforations of a well are identified, and measures of pressure along the perforations are determined according to the Single-Perforation Column Method described above.
  • step 92 pressure assignments are determined and propagated to the remained or non-perforated grid blocks according to suitable statistical methods as described in U. S. Patent Application No. 14/014,658 .
  • the All-Perforation Column Method produces the same results as the Single-Perforation Column Method, as illustrated schematically in Figures 8A and 8B and described above.
  • Figure 9 illustrates schematically the All-Perforation Column Method step 84 ( Figure 6 ) for a horizontal well model 93 having a plurality of well perforations 94 as shown.
  • pressure assignments are determined and propagated to the remained or non-perforated grid blocks 95 ( Figure 9 ) of the horizontal well model 93 according to suitable statistical methods as described in U. S. Patent Application No. 14/014,658 , as indicated schematically at 96.
  • step 40 for pressure computation along the well completions of a selected one of the three alternatives: All Perforation Method; Single-Perforation Column Method or All-Perforation Column Method in the manner described above, the reservoir model has been adjusted.
  • the reservoir model M indicates propagated pressure measures which incorporate measured reservoir pressures as adjusted to indicate the effects of physics and geology on the reservoir and its fluids indicated by reservoir simulation processing.
  • a user is able to specify one of several techniques for data filtering, such as the type known as a Distance Weighted Moving Average or DWMA.
  • the DWMA filtering is a nonlinear filter, designed to be a robust version of a traditional moving average.
  • DWMA filtering is then performed during step 98 to reduce the impact of outlier propagated pressure measures in the reservoir model data.
  • the result of step 98, as indicated at 100 is a 3-dimensional pressure array of reservoir pressure data which is stored for further processing by the data processing system D.
  • the 3-dimensional grid pressure array indicated at 100 is then in step 102 according to the present invention collapsed or changed in format from a 3-dimensional pressure array to 2-dimensional pressure of a region of interest (or entirety of the reservoir) in the reservoir M.
  • step 102 There are a number of methods of collapsing the 3-dimensional grid to 2-dimensional maps, the simplest being simple averaging of the propagated pressure measures of the model adjacent the various specified map co-ordinates for 2-dimensional map being formed.
  • Pore-Volume Weighted Averaging for step 102 is utilized for collapsing the 3-dimensional grid to a 2-dimensional map of the region of interest.
  • Examples of such pore-volume weighted averaging to indicate average reservoir pressure for 2-dimensional isobaric maps are set forth below. Reference is made to the Nomenclature Section for an explanation of the physical measures indicated in the relationships of pore-volume weighted averaging expressed.
  • a user engineer or analyst is able to select an area of interest in the reservoir model M for which an isobaric 2-dimensional pressure map is to be formed.
  • the display is formed by the data processing system D during performance of step 104 of Figure 3 .
  • an engineer can specify an area of interest using an n-sided polygon where all variety of isobaric maps can be generated as indicated at step 106 along with average reservoir pressure calculations.
  • an example plot 140 represents a simulated 2-dimensional isobaric pressure map which could be obtained according to the present invention based on governing equations and relationships for a selected area of interest, and representing the interplay of principles of thermodynamics and geophysics formed according to the present invention.
  • Example values of SBHP survey data and sample perforation location data according coordinates for perforations are set forth below: FIELD WELL NO. 10/1/2015 ABCD 1 1500 ABCD 2 1300 ABCD 3 2000 ABCD 4 1655 ABCD 5 1582 ABCD 6 1340 ABCD 7 1790 ABCD 8 2469 ABCD 9 4467 ABCD 10 1200 ABCD 11 1400 ABCD 12 4500 ABCD 13 3000 ABCD 14 1500 ABCD 15 4064 ABCD 16 3261 ABCD 17 2531 ABCD 18 5092 ABCD 19 2452 ABCD 20 2401 ABCD 21 2244 ABCD 22 2194
  • the map plot 140 indicates by x, y co-ordinates the location in a reservoir model M of a selected area of interest and by contour lines 142, areas of common isobaric pressures at the location. Indications of pressures represented as the 2-dimensional isobaric pressure areas in the reservoir map 140 may be indicated by variations in color, as schematically shown by varying stipple patterns in areas of common pressure within the contour lines.
  • the pressures displayed indicate reservoir pressures over the area of interest while also taking into account geological features, aerial and vertical heterogeneity, and numerical model constraints.
  • the maps formed according to the present invention are not merely estimates of reservoir pressures based only on readings from pressure measurement instrumentation located at a limited number of wells in a reservoir.
  • Figure 10A is a graphical depiction of an example specification of I, J, and K co-ordinates, having reference to Figure 10B for the orientation of the axial disposition of the co-ordinates. Set forth below are examples of numerical dimensions.
  • the area of interest given model dimensions (I x J x K): 500 x 300 x 200, is bounded by 4-sided polygon indicated by these two corners (1, 1, 1) and (500, 300, 200) is basically the whole reservoir. Therefore the numerical co-ordinates of the user-specified region of interest in the reservoir model M are as set forth below in Table 1: Table 1 1 1 1 300 1 200 500 500 1 300 1 200 1 500 1 1 1 200 1 500 300 300 1 200
  • the numerical co-ordinates of the user-specified region of interest in the reservoir model M are as set forth below in Table 2: Table 2 1 1 50 100 10 190 350 350 50 100 10 190 1 350 50 50 10 190 1 350 100 100 10 190
  • the data processing system D includes a computer C having a processor 150 and memory 152 coupled to the processor 100 to store operating instructions, control information and database records therein.
  • the data processing system D can be a computer of any conventional type of suitable processing capacity, such as a mainframe, a personal computer, laptop computer, or any other suitable processing apparatus. It should thus be understood that a number of commercially available data processing systems and types of computers may be used for this purpose.
  • the data processing system also operates as a reservoir simulator R for simulation of performance and for forecasting of production from the reservoir M.
  • the simulator may thus be of the type described and shown in U. S. Patent No. 7,526,418 .
  • the computer C has a user interface 154 and an output data display 156 for displaying output data or records of three-dimensional reservoir pressure determination using real time pressure data from downhole gauges according to the present invention.
  • the output display 156 includes components such as a printer and an output display screen capable of providing printed output information or visible displays in the form of graphs, data sheets, graphical images, data plots and the like as output records or images.
  • the user interface 154 of data processing system D also includes a suitable user input device or input/output control unit 158 to provide a user access to control or access information and database records and operate the computer C.
  • Data processing system D further includes a database 160 stored in computer memory, which may be internal memory 152, or an external, networked, or non-networked memory as indicated at 162 in an associated database server 164.
  • the data processing system D includes program code 166 stored in non-transitory form in memory 152 of the computer C.
  • the program code 166 according to the present invention is in the form of non-transitory computer operable instructions causing the data processor 100 to perform the computer implemented method of the present invention in the manner described above and illustrated in Figure 3 .
  • program code 166 may be in the form of microcode, programs, routines, or symbolic computer operable languages that provide a specific set of ordered operations that control the functioning of the data processing system D and direct its operation.
  • the instructions of program code 166 may be stored in non-transitory form in memory 152 of the computer C, or on computer diskette, magnetic tape, conventional hard disk drive, electronic read-only memory, optical storage device, or other appropriate non-transitory data storage device having a computer usable medium stored thereon.
  • Program code 166 may also be contained on a data storage device such as server 164 as a non-transitory computer readable medium.
  • SBHP Bottom-Hole Pressure
  • pressure survey data measured at or near the depth of a producing formation interval data is entered and honored at the well locations with respect to the desired reference datum depth.
  • SBHP pressures as control points
  • the 3-dimensional pressure between the wells is estimated based on results of the numerical simulation by reservoir simulator R based on governing equations and relationships representing actual thermodynamics and geophysics, as well as the most updated geological realization of the subsurface reservoir illustrated as model M.
  • the present invention reduces turnaround time for generation of maps and quality checking the data contents displayed in the maps and stored in the data processing system for evaluation of further processing or analysis.
  • the integration between the SBHP pressure points and simulation pressure results in a 3D grid populated with estimated reservoir pressure based on appropriate reliability and conformance with statistical quality analysis and control methods (such as Distance-Weighted Moving Average or DWMA).
  • the data processing system D then adjusts the pressure values to the datum reference depth, if needed.
  • Several alternative methods are then available for collapsing the 3-dimensional pressure grid array into a single layer (2-dimensional) while also taking into account geological features, aerial and vertical heterogeneity, and numerical model constraints.
  • the resultant product, a 2-dimensional isobaric map of a reservoir region of interest is the provided and made available to a variety of visualization and quality control tools for reservoir management engineers to utilize.

Claims (7)

  1. Procédé mis en oeuvre par ordinateur de formation, avec un système de traitement de données, d'une carte de pressions bidimensionnelle de pressions de réservoir dans une région d'intérêt dans un réservoir souterrain de production d'hydrocarbures divisé à des fins de modélisation en un modèle de réservoir divisé en tant que matrice d'un réseau de cellules s'étendant sur les trois dimensions du réservoir, le réservoir présentant une pluralité de puits avec des perforations pour un passage de fluide depuis le réservoir jusque dans le puits, des puits sélectionnés présentant des systèmes de mesure de pression de fond de trou installés en leur sein, la matrice d'un réseau de cellules du modèle de réservoir comprenant des cellules de puits au niveau des emplacements des puits et des cellules de réservoir au niveau des cellules restantes du réseau, le procédé comprenant les étapes de traitement par ordinateur consistant à :
    (a) obtenir, au moyen d'un système de mesure de pression de fond de trou (20), des données de pression (30) pour les puits, le système de mesure de pression de fond de trou comprenant des capteurs de fond de trou (22) installés dans un sous-ensemble des puits (G), les données de pression pour les puits comprenant des mesures de pression collectées à partir des capteurs de fond de trou installés dans le sous-ensemble des puits ;
    (b) réaliser des calculs de pressions simulées sur un simulateur de réservoir dans le système de traitement de données pour les cellules dans une matrice de cellules de puits pour une zone d'intérêt du réservoir (36) ;
    (c) alimenter des cellules de puits au niveau d'une perforation la plus haute de chacun des puits avec des valeurs de pression attribuées issues des données de pression reçues (39) ;
    (d) propager des valeurs de pression pour les cellules de puits des puits en dessous des perforations les plus hautes et vers les cellules de réservoir de la zone d'intérêt pour former une matrice de pression de réseau tridimensionnelle pour la zone d'intérêt (40) ;
    (e) réduire la matrice de pression de réseau tridimensionnelle à une couche bidimensionnelle de valeurs de pression pour la région d'intérêt (102) ;
    (f) assembler dans une mémoire du système de traitement de données la couche bidimensionnelle de valeurs de pression pour la région d'intérêt (106) ; et
    (g) former une carte d'images de sortie (140) de la couche bidimensionnelle de valeurs de pression pour la région d'intérêt pour une utilisation dans la gestion du réservoir.
  2. Procédé mis en oeuvre par ordinateur selon la revendication 1, incluant en outre l'étape consistant à réaliser un filtrage numérique des valeurs de pression propagées pour les cellules de puits des puits (98).
  3. Procédé mis en oeuvre par ordinateur selon la revendication 2, dans lequel le filtrage numérique réalisé comprend un filtrage de moyennes mobiles pondérées numérique.
  4. Procédé mis en oeuvre par ordinateur selon la revendication 1, dans lequel l'étape consistant à propager des valeurs de pression pour les cellules de puits des puits est réalisée en utilisant chacune des perforations pour les cellules d'un puits en tant que points de contrôle.
  5. Procédé mis en oeuvre par ordinateur selon la revendication 1, dans lequel l'étape consistant à propager des valeurs de pression pour les cellules de puits des puits est réalisée en utilisant une perforation unique en tant que point de contrôle.
  6. Procédé mis en oeuvre par ordinateur selon la revendication 1, dans lequel l'étape consistant à propager des valeurs de pression pour les cellules de puits des puits est réalisée en utilisant chacune des perforations pour les cellules d'un puits en tant que points de contrôle pour un tel puits.
  7. Procédé mis en oeuvre par ordinateur selon la revendication 1, dans lequel l'étape consistant à réduire la matrice de pression de réseau tridimensionnelle en une couche bidimensionnelle de valeurs de pression pour la région d'intérêt est réalisée en établissant une moyenne pondérée par le volume de pores.
EP17722360.9A 2016-05-04 2017-05-01 Estimation de pression de réservoir bidimensionnelle avec données de relevé de pression statique de fond de trou et modélisation de simulation intégrées Active EP3452698B1 (fr)

Applications Claiming Priority (2)

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US15/146,323 US10571604B2 (en) 2013-08-30 2016-05-04 Two dimensional reservoir pressure estimation with integrated static bottom-hole pressure survey data and simulation modeling
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