EP3452698B1

EP3452698B1 - Two dimensional reservoir pressure estimation with integrated static bottom hole pressure survey data and simulation modeling

Info

Publication number: EP3452698B1
Application number: EP17722360.9A
Authority: EP
Inventors: Umar A. Al-Nahdi; Ali A. AL-TURKI; Badr M. Al-Harbi; Sami A. AL-NUAIM
Original assignee: Saudi Arabian Oil Co
Current assignee: Saudi Arabian Oil Co
Priority date: 2016-05-04
Filing date: 2017-05-01
Publication date: 2023-06-28
Anticipated expiration: 2037-05-01
Also published as: EP3452698A1; WO2017192423A1; CN109072692B; CN109072692A

Description

BACKGROUND OF THE INVENTION

1. Field of the Invention

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.

2. Description of the Related Art

In the oil and gas industries, massive amounts of data are required to be processed for computerized simulation, modeling and analysis for exploration and production purposes. For example, the development of 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.
It is desirable to be able to monitor pressure conditions in such a reservoir so that production is optimized. Adjustments can be made in production or injection rates to remove undesirable high or low pressure regions that might be observed from such monitoring. For reservoir planning purposes, 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.
In simulation models, 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.
For reservoirs of this type, 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. Typically, 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.
Thus, only a relatively small number of wells in a reservoir have such pressure gauges and as mentioned, 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.
Therefore, the conditions and spatial quantity under which the actual well pressure is measured are completely different than the reservoir pressure which reservoir engineers are interested in for reservoir production optimization. Pressure measurements at the limited number of wells having gauges in the reservoir do not provide an accurate indication of reservoir pressure conditions of interest over the full 3-dimensional extent of the reservoir.
So far as is known, in previous isobaric mapping techniques, the well's static bottom-hole pressure (SBHP) readings were used to generate isobaric maps. Each SBHP reading was a control point based on which the isobaric map was generated. The interpolation between the control points was a simple linear interpolation that did not account for geological features or for reservoir dynamics during production.
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.

SUMMARY OF THE INVENTION

Briefly, 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.

BRIEF DESCRIPTION OF THE DRAWINGS

Figure 1 is a schematic diagram of a model of a subsurface hydrocarbon reservoir.
Figure 2 is a schematic diagram showing a pressure downhole measuring system installed in a selected number of wells in the reservoir of Figure 1.
Figure 3 is a functional block diagram of a set of data processing steps performed in a data processing system for two dimensional reservoir pressure estimation with integrated static bottom-hole pressure survey data and simulation modeling according to the present invention.
Figures 4, 5 and 6 are functional block diagrams of a set of data processing steps performed in connection with processing according to Figure 3.
Figures 7A, 7B and 7C are schematic diagrams of grid cells of a subsurface reservoir model illustrative of the workflow according to Figures 3 and 4 for propagating pressure determinations to each perforation in a vertical well.
Figures 8A and 8B are schematic diagrams of grid cells of a subsurface reservoir model illustrative of the workflow according to Figures 3 and 5 for propagating pressure determinations for a single perforation in a vertical well to other grid cells in the reservoir.
Figure 9 is a schematic diagram of a subsurface reservoir model illustrative of the workflow according to Figures 3 and 6 for propagating pressure determinations for a single perforation in a horizontal well to other grid cells in the reservoir.
Figures 10A and 10B are schematic diagrams illustrating notations for directions and for grid nomenclature in a reservoir model.
Figure 11 is a schematic block diagram of a data processing system for two dimensional reservoir pressure estimation with integrated static bottom-hole pressure survey data and simulation modeling according to the present invention.
Figure 12 is an example simulated plot of a 2-dimensional isobaric pressure map based on governing reservoir actual thermodynamics and geophysics relationships according to the present invention.

DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

In the drawings, 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.
For a giant reservoir, 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.
For reservoirs of this type, 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. Typically, 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.
Thus, only key wells in a reservoir have such pressure gauges and as mentioned, 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. As indicated, 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. 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.

Nomenclature

Pav: Average reservoir pressure
Pcolav: Average reservoir pressure for a column of grid blocks
PSBHP: Static Bottom-hole pressure
ΔPcf: Pressure correction factor for a column of cells
Pcal: i-Reservoir calculated pressure
(PVi): Pore volume of cell or grid block i, where i=1, 2.....n
(BV)i: Bulk Volume of cell or grid block i, where i=1,2.....n
PVi = (BV)I ∗ Øi: (Gridblock Bulk Volume) * porosity of grid block i where i=1,2.....n
(Sw)i: Water saturation
(1 - Sw)i: Hydrocarbon Saturation at grid block i where i=1,2.....n
I: Grid block index in x-direction with reference to a layer in the 3D reservoir grid
J: Grid block index in y-direction with reference to a layer in the 3D reservoir grid
K: Grid block index in z-direction with reference to a column in the 3D reservoir grid

Subscripts

C:: column
cf:: correction factor
cal:: calculated
colav:: column average
e:: grid block index
av:: average
i:: grid block index
s:: start
w:: water
HC:: hydrocarbon
avHC:: hydrocarbon weighted average
avWC:: average pressure above contacts (free phase table)
avHCWC:: hydrocarbon average above contacts (free phase table)

Turning to Figure 3, 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. In connection with the processing according to the flow chart F, 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.
As shown at 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.
The reservoir simulation is then performed by reservoir simulator R (Figure 10) during step 36 with the quality-checked and verified updates to perforation and production/injection data which have been updated during step 34 to the date of interest. During 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.
During step 38, the pressure gradients determined by reservoir simulator R as a result of step 36 are evaluated. In the evaluation during step 38, 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.
In 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.
According to the present invention, 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.

All Perforation Method

As shown in Figure 4, the All Perforation processing 42 begins with step 48 where SBHP values are assigned to the first or uppermost perforation in a well. During step 50, 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.
As shown schematically in Figure 7A, during All Perforation processing step 42 SBHP values are assigned to the first or uppermost perforation 54 in an example vertical well 56. Figure 7B 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.

Single-Perforation Column Method

In the Single-Perforation Column Method shown at 64 (Figure 5), only a first perforation of 56 well is considered as the pivot for calculating pressure along the well and away from it. As shown in Figure 5, the All Perforation processing 64 begins with step 66 where after the first perforation is identified and the column of cells where, the first perforation is located is marked, the average column pressure (P_colav ) is determined from the simulation model: $P_{colav} = \frac{\sum_{i = 1}^{c} (P_{i})}{c}$
During step 68, a correction factor (ΔP_cf ) is determined by subtracting the pressure survey reading SBHP (P_SBHP ) from the average column pressure P_colav determined during step 66: ${ΔP}_{cf} = P_{colav} - P_{SBHP}$
During step 70, for each cell pressure value from simulation model, the correction factor (ΔP_cf ) is subtracted from cell pressure (P_sim ) and the resultant i-Reservoir calculated pressure value P_cal assigned to i-Reservoir grid pressure, as follows: $P_{cal} = P_{sim} - {ΔP}_{cf}$
In this manner pressure for each of the grid blocks is determined. Figures 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. As a result, the average column pressure is the (P_SBHP ).

All-Perforation Column Method

For the All-Perforation Column Method as shown at 84 (Figure 6), 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. As shown in Figure 6, the All Perforation processing begins with step 86, where the average column pressure (P_colavi ) is determined for the perforations of each column i from the simulation model: $(P_{{colav}_{i}}) = \frac{\sum_{i = 1}^{c} (P_{i})}{c}$
During step 88, a correction factor (ΔP_cfi ) is determined for each column i by subtracting the pressure survey reading SBHP (P_SBHP ) from the average column pressure (P_colavi ) determined during step 86: ${ΔP}_{{cf}_{i}} = P_{{colav}_{i}} - P_{SBHP}$
Then, during step 90, for each column i and for each cell pressure value from simulation model in that column, the correction factor (ΔP_cfi ) is subtracted from cell pressure (P_sim ) and assigned as the pressure value P_cal to i-Reservoir grid pressure: $P_{cal} = P_{sim} - {ΔP}_{{cf}_{i}}$
Next, in 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 . For a vertical well, 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. In step 92 of the All-Perforation Column Method, 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.
After performance of step 40 (Figure 3) 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.
During step 97 (Figure 3), 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. 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.
Preferably, however, one of several forms of 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.
Pore-Volume Weighted Average Reservoir Pressure $P_{av} = \frac{\sum_{i = 1}^{n} (P_{i} ({PV}_{i}))}{\sum_{i = 1}^{n} ({PV}_{i})}$
Hydrocarbon Pore-Volume Weighted Average Reservoir Pressure $P_{avHC} = \frac{\sum_{i = 1}^{n} (P_{i} [{(PV)}_{i} * {(1 - S_{w})}_{i}])}{\sum_{i = 1}^{n} {(PV)}_{i}}$
Pore-Volume Weighted Average Reservoir Pressure Above Free Water Table $P_{avWC} = \frac{\sum_{i = 1}^{n} (P_{i} ({PV}_{i}))}{\sum_{i = 1}^{n} ({PV}_{i})}$
where i is the index of all grid block with depth greater than the specified contact's depth.
Hydrocarbon Pore-Volume Weighted Average Reservoir Pressure Above Free Water Table $P_{avHCWC} = \frac{\sum_{i = 1}^{n} (P_{i} [{(PV)}_{i} * {(1 - S_{w})}_{i}])}{\sum_{i = 1}^{n} {(PV)}_{i}}$
where i is the index of all grid block with depth greater than the specified contact's depth.
As mentioned 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. For this processing step, 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.
As shown in Figure 12, 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

Sample SBHP Survey Data

WELLS_BLOCK

WELL_Name=ABCD0001

PERF I=301 J=71 K=51 Rf=1.0 CD='Z' Skin=1.0/ MDEPTH=3873.5
PERF I=301 J=71 K=52 Rf=1.0 CD='Z' Skin=2.0 / MDEPTH=3880.5
PERF I=301 J=71 K=53 Rf=1.0 CD='Z' Skin=1.0 / MDEPTH=3887.5
PERF I=301 J=71 K=54 Rf=1.0 CD='Z' Skin=0.0 / MDEPTH=3898.5
PERF I=301 J=71 K=55 Rf=1.0 CD='Z' Skin=0.0 / MDEPTH=3913.5
PERF I=301 J=71 K=56 Rf=1.0 CD='Z' Skin=0.0/ MDEPTH=3928.5
PERF I=301 J=71 K=57 Rf=1.0 CD='Z' Skin=1.0 / MDEPTH=3941.5

WELL_Name=ABCD0002

PERF I=101 J=71 K=41 Rf=1.0 CD='Z' Skin=0.0 / MDEPTH=4873.0
PERF I=101 J=71 K=42 Rf=1.1 CD='Y' Skin=0.0 / MDEPTH=4880.0
PERF I=101 J=71 K=43 Rf=1.0 CD='Z' Skin=0.0 / MDEPTH=4887.0
PERF I=101 J=71 K=44 Rf=1.0 CD='Z' Skin=0.0 / MDEPTH=4898.0
PERF I=101 J=71 K=45 Rf=1.2 CD='Z' Skin=0.0 / MDEPTH=4913.0
PERF I=101 J=71 K=46 Rf=1.0 CD='Y' Skin=0.0 / MDEPTH=4928.0
PERF I=101J=71 K=47 Rf=1.3 CD='Z' Skin=0.0 / MDEPTH=4941.0

ENDWELLS_BLOCK

DATE DEC 12010

WELLS_BLOCKS

WELL_Name=ABCD0005

PERF I=20 J=113 K=83 Rf=1.0CD='Z' Skin=0.0/ MDEPTH=3890.50
PERF I=21 J=113 K=83 Rf=1.1 CD='X' Skin=0.0 / MDEPTH=3900.50
PERF I=21 J=113 K=84 Rf=1.0 CD='Z' Skin=0.0/ MDEPTH=3887.50
PERF I=22 J=113 K=81 Rf=1.0 CD='X' Skin=3.0 / MDEPTH=3887.50
PERF I=30 J=113 K=81 Rf=1.2 CD='X' Skin=0.0 / MDEPTH=3887.50
PERF I=31 J=113 K=83 Rf=1.0CD='X' Skin=0.0/ MDEPTH=3887.50
PERF I=32 J=113 K=83 Rf=1.3 CD='Z' Skin=0.0/ MDEPTH=3890.50

ENDWELLS_BLOCK

As can be seen in Figure 12, 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.

Example 1

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

Example 2

The area of interest, given model dimensions (I x J x K): 500 x 300 x 200 is bounded by corners (1, 50, 10) and (350, 100, 190). 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
As illustrated in Figure 11, the data processing system D according to the present invention 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. As indicated, 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.
It should be noted that 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.
With the present invention, Bottom-Hole Pressure (SBHP) or 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. Establishing the wells 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.
The invention has been sufficiently described so that a person with average knowledge in the matter may reproduce and obtain the results mentioned in the invention herein Nonetheless, any skilled person in the field of technique, subject of the invention herein, may carry out modifications not described in the request herein, to apply these modifications to a determined methodology, or in the performance of the same, requires the claimed matter in the following claims; such techniques and procedures shall be covered within the scope of the invention.
It should be noted and understood that there can be improvements and modifications made of the present invention described in detail above without departing from the scope of the invention as set forth in the accompanying claims.

Claims

A 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 method comprising the computer processing steps of:
(a) obtaining, by way of a downhole pressure measurement system (20), pressure data (30) for the wells, the downhole pressure measurement system comprising downhole sensors (22) installed in a subset of the wells (G), the pressure data for the wells comprising pressure measurements collected from downhole sensors installed in the subset of the wells;

(b) performing 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 (36);

(c) populating well cells at an uppermost perforation of each of the wells with assigned pressure values from the received pressure data (39);

(d) propagating 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 (40);

(e) reducing the three-dimensional grid pressure array to a two-dimensional layer of pressure values for the region of interest (102);

(f) assembling in memory of the data processing system the two-dimensional layer of pressure values for the region of interest (106); and

(g) forming an output image map (140) of the two-dimensional layer of pressure values for the region of interest for use in management of the reservoir.
The computer implemented method of Claim 1, further including the step of performing digital filtering of the propagated pressure values for the well cells of the wells (98).
The computer implemented method of Claim 2, wherein the digital filtering performed comprises digital weighted moving average filtering.
The computer implemented method of Claim 1, wherein the step of propagating pressure values for the well cells of the wells is performed using each of the perforations for the cells of a well as control points.
The computer implemented method of Claim 1, wherein the step of propagating pressure values for the well cells of the wells is performed using a single perforation as a control point.
The computer implemented method of Claim 1, wherein the step of propagating pressure values for the well cells of the wells is performed using each of the perforations for the cells of a well as control points for such well.
The computer implemented method of Claim 1, wherein the step of reducing the three-dimensional grid pressure array to a two-dimensional layer of pressure values for the region of interest is performed by pore-volume weighted averaging.