USRE41999E1 - System and method for real time reservoir management - Google Patents
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- USRE41999E1 USRE41999E1 US11/704,369 US70436907A USRE41999E US RE41999 E1 USRE41999 E1 US RE41999E1 US 70436907 A US70436907 A US 70436907A US RE41999 E USRE41999 E US RE41999E
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- E—FIXED CONSTRUCTIONS
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- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/14—Obtaining from a multiple-zone well
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/20—Displacing by water
Definitions
- Reissue application Ser. No. 12 / 436 , 632 is a divisional of this reissue application Ser. No. 11 / 704 , 369 .
- both producers and injectors would be planned in accordance with a reservoir development plan.
- more dynamic data would become available, thus, allowing the engineers and geoscientists to better understand how the reservoir rock was distributed and how the fluids were flowing.
- an improved understanding of the reservoir was used to adjust the reservoir development plan resulting in the familiar pattern of recompletion, sidetracks, infill drilling, well abandonment, etc. Unfortunately, not until the time at which the field was abandoned, and when the information is the least useful, did reservoir understanding reach its maximum.
- reservoir engineers and geoscientists have made assessments of reservoir characteristics and optimized production using down hole test data taken at selected intervals.
- data usually includes traditional pressure, temperature and flow data is well known in the art.
- Reservoir engineers have also had access to production data for the individual wells in a reservoir.
- Such data as oil, water and gas flow rates are generally obtained by selectively testing production from the selected well at selected intervals.
- down hole characteristics which may be monitored with such equipment include: temperature, pressure, fluid flow rate and type, formation resistivity, crosswell and acoustic seismometry, perforation depth, fluid characteristics and logging data.
- hydrocarbon production performance may be enhanced by activating local operations in additional downhole equipment.
- a similar type of casing assembly used for gathering data is described and illustrated in international PCT application WO 98/12417, assigned to BP Exploration Operating Company Limited, the disclosure of which is incorporated by reference.
- 4-D seismic processing Another important emerging technology that may have a substantial impact on managing reservoirs is time lapsed seismic, often referred to a 4-D seismic processing.
- seismic surveys were conducted only for exploration purposes.
- incremental differences in seismic data gathered over time are becoming useful as a reservoir management tool to potentially detect dynamic reservoir fluid movement. This is accomplished by removing the non-time varying geologic seismic elements to produce a direct image of the time-varying changes caused by fluid flow in the reservoir.
- 4-D seismic processing can locate bypassed oil to optimize infill drilling and flood pattern.
- 4-D seismic processing can be used to enhance the reservoir model and history match flow simulations.
- a reservoir monitoring system comprising: a plurality of permanently coupled remote sensor nodes, wherein each node comprises a plurality of seismic sensors and a digitizer for analog signals; a concentrator of signals received from the plurality of permanently coupled remote sensor nodes; a plurality of remote transmission lines which independently connect each of the plurality of remote sensor nodes to the concentrator, a recorder of the concentrated signals from the concentrator, and a transmission line which connects the concentrator to the recorder.
- the system is used to transmit remote data signals independently from each node of the plurality of permanently coupled remote sensor nodes to a concentrator and then transmit the concentrated data signals to a recorder.
- Such advanced systems of gathering seismic data may be used in the reservoir management system of the present invention as disclosed hereinafter in the Detailed Description section of the application.
- geoscientists, geologists and geophysicists (sometimes in conjunction with reservoir engineers) analyzed well log data, core data and SDL data.
- the data was and may currently be processed in log processing/interpretation programs that are commercially available, such as Petroworks and DPP.
- Seismic data may be processed in programs such as Seisworks and then the log data and seismic data are processed together and geostatistics applied to create a geocellular model.
- reservoir engineers may use reservoir simulators such as VIP or Eclipse to analyze the reservoir.
- Nodal analysis programs such as WEM, Prosper and Openflow have been-used in conjunction with material balance programs and economic analysis programs such as Aries and ResEV to generate a desired field wide production forecast.
- WEM WEM
- Prosper Prosper
- Openflow material balance programs
- economic analysis programs such as Aries and ResEV to generate a desired field wide production forecast.
- selected wells may be produced at selected rates to obtain the selected forecast rate.
- target injection rates and zonal profiles are determined to obtain the field wide injection rates.
- the present invention comprises a field wide management system for a petroleum reservoir on a real time basis.
- a field wide management system includes a suite of tools (computer programs) that seamlessly interface with each other to generate a field wide production and injection forecast.
- the resultant output of such a system is the real time control of downhole production and injection control devices such as chokes, valves and other flow control devices and real time control of surface production and injection control devices.
- Such a system and method of real time field wide reservoir management provides for better reservoir management, thereby maximizing the value of the asset to its owner.
- FIG. 1 is a block diagram of the method of field wide reservoir management of the present invention
- FIG. 2 is a cross section view of a typical well completion system that may be used in the practice of the present invention
- FIG. 3 is a cross section of a flat back cable that may be used to communicate data from sensors located in a wellbore to the data management and analysis functions of the present invention and communicate commands from the reservoir management system of the present invention to adjust downhole well control devices;
- FIG. 4 is a block diagram of the system of real time reservoir management of the present invention
- FIG. 4 is a generalized diagrammatic illustration of one exemplary embodiment of the system of FIG. 4 ;
- FIG. 5 illustrates exemplary operations which can be performed by the controller of FIG. 4A to implement the data management function of FIG. 4 ;
- FIG. 6 illustrates exemplary operations which can be performed by the controller of FIG. 4A to implement the nodal analysis function and the material balance function of FIG. 4 ;
- FIG. 7 illustrates exemplary operations which can be performed by the controller of FIG. 4A to implement the reservoir simulation function of FIG. 4 ;
- FIG. 8 illustrates exemplary operations which can be performed by the controller of FIG. 4A to implement the risked economics function of FIG. 4 .
- the present invention comprises a method and system of real time field wide reservoir management.
- a system includes a suite of tools (computer programs of the type listed in Table 1) that seamlessly interface with each other in accordance with the method to generate a field wide production and injection forecast. It will be understood by those skilled in the art that the practice of the present invention is not limited to the use of the programs disclosed in Table 1. Programs listed in Table 1 are merely some of the programs presently available for practice of the invention.
- the resultant output of the system and method of field wide reservoir management is the real time control of downhole production and injection control devices such as chokes, valves, and other flow control devices (as illustrated in FIGS. 2 and 3 and otherwise known in the art) and real time control of surface production and injection control devices (as known in the art).
- the real time control described herein need not necessarily be instantaneous, but can be delayed depending on how the control is communicated to the downhole production and injection control devices.
- Field wide reservoir management does not require that every well in a field be controlled.
- production/injection production and/or injection
- geologic data geologic data.
- Production/injection data includes accurate pressure, temperature, viscosity, flow rate and compositional profiles made available continuously on a real time basis or, alternatively, available as selected well test data or daily average data.
- production/injection data may include downhole production data 1 , seabed production data 2 and surface production data 3 . It will be understood that the present invention may be used with land based petroleum reservoirs as well as subsea petroleum reservoirs.
- Production/injection data is pre-processed using pressure transient analysis in computer programs such as Saphir by Kappa Engineering or PTA by Geographix to output reservoir permeability, reservoir pressure, permeability-feet and the distance to the reservoir boundaries.
- geologic data includes log data, core data and SDL data represented by block 5 and seismic data represented by block 7 .
- Block 5 data is pre-processed as illustrated in block 6 using such computer programs such as Petroworks by Landmark Graphics, Prizm by Geographix and DPP by Halliburton to obtain water and oil saturations, porosity, and clay content.
- Block 5 data is also processed in stratigraphy programs as noted in block 6 A by programs such as Stratworks by Landmark Graphics and may be further pre-processed to map the reservoir as noted in block 6 B using a Z-Map program by Landmark Graphics.
- Geologic data also includes seismic data block 7 that may be conventional or real time 4D seismic data (as discussed in the background section). Seismic data may be collected conventionally by periodically placing an array of hydrophones and geophones at selected places in the reservoir or 4D seismic may be collected on a real time basis using geophones placed in wells. Block 7 seismic data is processed and interpreted as illustrated in block 8 by such programs as Seisworks and Earthcube by Landmark Graphics to obtain hydrocarbon indicators, stratigraphy and structure.
- Output from blocks 6 and 8 is further pre-processed as illustrated in block 9 to obtain geostatistics using Sigmaview by Landmark Graphics.
- Output from blocks 8 , 9 and 6 B are input into the Geocellular (Earthmode) programs illustrated by block 10 and processed using the Stratamodel by Landmark Graphics.
- the resultant output of block 10 is then unscaled as noted in block 11 in Geolink by Landmark Graphics to obtain a reservoir simulation model.
- Output from upscaling 11 is input into the data management function of block 12 .
- Production/injection data represented by downhole production 1 , seabed production 2 and surface production 3 may be input directly into the data management function 12 (as illustrated by the dotted lines) or pre-processed using pressure transient analysis as illustrated in block 4 as previously discussed.
- Data management programs may include Openworks, Open/Explorer, TOW/cs and DSS32, all available from Landmark Graphics and Finder available from Geoquest.
- Reservoir simulation may be accomplished by using data from the data management function 12 using VIP by Landmark Graphics or Eclipse by Geoquest.
- Material Balance calculations may be performed using data from the reservoir simulation 13 and data management function 12 to determine hydrocarbon volumes, reservoir drive mechanisms and production profiles, using MBAL program of Petroleum Experts.
- Nodal Analysis 15 may be performed using the material balance data output of 14 and reservoir simulation data of 13 and other data such as wellbore configuration and surface facility configurations to determine rate versus pressure for various system configurations and constraints using such programs as WEM by P. E. Moseley and Associates, Prosper by Petroleum Experts, and Openflow by Geographix.
- Risked Economics 16 may be performed using Aries or ResEV by Landmark Graphics to determine an optimum field wide production/injection rate.
- the target field wide production/injection rate may be fixed at a predetermined rate by factors such as product (oil and gas) transportation logistics, governmental controls, gas, oil or water processing facility limitations, etc. In either scenario, the target field wide production/injection rate may be allocated back to individual wells.
- the reservoir management system of the present invention After production/injection for individual wells is calculated the reservoir management system of the present invention generates and transmits a real time signal used to adjust one or more interval control valves located in one or more wells or adjust one or more subsea control valves or one or more surface production control valves to obtain the desired flow or injection rate.
- transmission of the real time signal is not necessarily instantaneous, and can be delayed depending on the communication method.
- the reservoir management system may signal an operator to adjust a valve. The operator may then travel into the field to make the adjustment or may telephone another operator near the valve to make the adjustment. Also, it will be understood by those skilled in the art that an inter-relationship exists between the interval control valves. When one is opened, another may be closed.
- the desired production rate for an individual well may be input directly back into the data management function 12 and actual production from a well is compared to the target rate on a real time basis.
- the system may include programming for a band width of acceptable variances from the target rate such that an adjustment is only performed when the rate is outside the set point.
- Opening or closing a control valve 17 to the determined position may have an almost immediate effect on the production/injection data represented by blocks 1 , 2 , 3 ; however, on a long term basis the reservoir as a whole is impacted and geologic data represented by blocks 5 and 7 will be affected (See dotted lines from control valve 17 ).
- the present invention continually performs iterative calculations as illustrated in box 19 using reservoir simulation 13 , material balance 14 , nodal analysis 15 and risked economics 16 to continuously calculate a desired field wide production rate and provide real time control of production/injection control devices.
- the method on field wide reservoir management incorporates the concept of “closing the loop” wherein actual production data from individual wells and on a field basis.
- the reservoir may be broken into discreet reservoir management intervals—typically a group of sands that are expected to behave as one, possibly with shales above and below.
- zonal isolation packers may be used to separate the producing and/or injection zones into management intervals.
- An example reservoir management interval might be 30 to 100 feet.
- variable chokes may be used to regulate the flow of fluids into or out of the reservoir management interval.
- SCRAMSJ is a completion system that includes an integrated data-acquisition and control network.
- the system uses permanent downhole sensors and pressure-control devices as well known in the art that are operated remotely through a control network from the surface without the need for traditional well-intervention techniques.
- continuous monitoring of downhole pressure, temperatures, and other parameters has been available in the industry for several decades, the recent developments providing for real-time subsurface production and injection control create a significant opportunity for cost reductions and improvements in ultimate hydrocarbon recovery. Improving well productivity, accelerating production, and increasing total recovery are compelling justifications for use of this system.
- the components of the SCRAMSJ System 100 may include:
- interval control valves 110 which provide an annulus to tubing flow path 102 and incorporates sensors 130 for reservoir data acquisition.
- the system 100 and the interval control valve 110 includes a choking device that isolate the reservoir from the production tubing 150 . It will be understood by those skilled in the art that there is an inter-relationship between one control valve and another as one valve is directed to open another control valve may be directed to close;
- an HF Retrievable Production Packer 160 provides a tubing-to-casing seal and pressure barrier, isolates zones and/or laterals from the well bore 108 and allows passage of the umbilical 120 .
- the packer 160 may be set using one-trip completion and installation and retrieval.
- the packer 160 is a hydraulically set packer that may be set using the system data communications and hydraulic power components.
- the system may also include other components as well known in the industry including SCSSV 131 , SCSSV control line 132 , gas lift device 134 , and disconnect device 136 . It will be understood by those skilled in the art that the well bore log may be cased partially having an open hole completion or may be cased entirely. It will also be understood that the system may be used in multilateral completions;
- SEGNETJ Protocol Software is used to communicate with and power the SCRAMSJ system.
- the SEGNETJ software accommodates third party products and provides a redundant system capable of by-passing failed units on a bus of the system;
- a dual flatback umbilical 120 which incorporates electro/hydraulic lines provides SEGNET communication and control and allows reservoir data acquired by the system to be transmitted to the surface.
- the flatback 120 comprises two galvanized mild steel bumber bars 121 and 122 and an incolony 1 ⁇ 4 inch tube 123 and 124 . Inside tube 124 is a copper conductor 125 .
- the flatback 120 is encased in a metal armor 126 ; and
- a surface control unit 160 operates completion tools, monitors the communications system and interfaces with other communication and control systems. It will be understood that an interrelationship exists between flow control devices as one is directed to open another may be directed to close.
- these blocks represent sensors as illustrated in FIG. 2 , or discussed in the background section (and/or as known in the art) used for collection of data such as pressure, temperature and volume, and 4D seismic. These sensors gather production/injection data from one or more wells that includes accurate pressure, temperature, viscosity, flow rate and compositional profiles available continuously on a real time basis.
- production/injection data is pre-processed using pressure transient analysis programs 24 in computer programs such as Saphir by Kappa Engineering or PTA by Geographix to output reservoir permeability, reservoir pressure, permeability-feet and the distance to the reservoir boundaries.
- geologic data including log, cores and SDL is collected with devices represented by blocks 25 and 26 as discussed in the background section, or by data sensors and collections well known in the art.
- Block 25 data is pre-processed as illustrated in block 26 using such computer programs Petroworks by Landmark Graphics, Prizm by Geographix and DPP by Halliburton to obtain water and oil saturations, porosity, and clay content.
- Block 25 data is also processed in stratigraphy programs as noted in block 26 A by programs such as Stratworks by Landmark Graphics and may be further pre-processed to map the reservoir as noted in block 26 B using a Z-Map program by Landmark Graphics.
- Geologic data also includes seismic data obtained from collectors known in the art and represented by block 27 that may be conventional or real time 4D seismic data (as discussed in the background section). Seismic data is processed and interpreted as illustrated in block 28 by such programs as Seisworks and Earthcube by Landmark Graphics to obtain hydrocarbon indicators, stratigraphy and structure.
- Output from blocks 26 and 28 is further pre-processed as illustrated in block 29 to obtain geostatistics using Sigma-view by Landmark Graphics.
- Output from blocks 28 , 29 and 26 B are input into the Geocellular (Earthmodel) programs illustrated by block 30 and processed using the Stratamodel by Landmark Graphics.
- the resultant output of block 30 is then upscaled as noted in block 31 in Geolink by Landmark Graphics to obtain a reservoir simulation model.
- Output from the upscaling program 31 is input into the data management function of block 32 .
- Production/injection data collected by downhole sensors 21 , seabed production sensors 22 and surface production sensors 23 may be input directly into the data management function 22 (as illustrated by the dotted lines) or pre-processed using pressure transient analysis as illustrated in block 22 as previously discussed.
- Data Management programs may include Openworks, Open/Explorer, TOW/cs and DSS32, all available from Landmark Graphics and Finder available from Geoquest.
- the Reservoir Simulation program 33 uses data from the data management function 32 , and can use data received from the Nodal Analysis program 35 to develop its simulation.
- the Reservoir Simulation program 33 can also output data to the Nodal Analysis program 35 .
- Examples of Reservoir Simulation programs include VIP by Landmark Graphics or Eclipse by Geoquest.
- the Material Balance program uses data from the reservoir simulation 33 and data management function 22 to determine hydrocarbon volumes, reservoir drive mechanisms and production profiles.
- One of the Material Balance programs known in the art is the MBAL program of Petroleum Experts.
- the Nodal Analysis program 35 uses data from the Material Balance program 34 and Reservoir Simulation program 33 and other data such as wellbore configuration and surface facility configurations to determine rate versus pressure for various system configurations. Additionally, the Nodal Analysis program 35 shares information with the Reservoir simulation program 33 , so that each program, Nodal Analysis 35 and Reservoir Simulation 33 , may iteratively update and account for changes in the output of the other. Nodal Analysis programs include WEM by P. E. Moseley and Associates, GAP and Prosper by Petroleum Experts, and Openflow by Geographix.
- Risked Economics programs 36 such as Aries or ResEV by Landmark Graphics determine the optimum field wide production/injection rate which may then be allocated back to individual wells.
- the reservoir management system of the present invention After production/injection by individual wells is calculated the reservoir management system of the present invention generates and transmits real time, though not necessarily instantaneous, signals (designated generally at 50 in FIG. 4 ) used to adjust interval control valves located in wells or adjust subsea control valves or surface production control valves to obtain the desired flow or injection rate.
- the desired production rate may be input directly back into the data management function 32 and actual production/injection from a well is compared to the target rate on a real time basis.
- Opening or closing a control valve 37 to the pre-determined position may have an almost immediate effect on the production/injection data collected by sensors represented by blocks 21 , 22 and 33 , however, on a long term basis, the reservoir as a whole is impacted and geologic data collected by sensors represented by blocks 25 and 27 will be affected (see dotted line from control valve 37 ).
- the present invention may be used to perform iterative calculations as illustrated in box 39 using the reservoir simulation program 23 , material balance program 24 , nodal analysis program 25 and risked economics program 26 to continuously calculate a desired field wide production rate and provide real time, though not necessarily instantaneous, control of production control devices.
- FIG. 4A is a generalized diagrammatic illustration of one exemplary embodiment of the system of FIG. 4 .
- the embodiment of FIG. 4A includes a controller 400 coupled to receive input information from information collectors 401 .
- the controller 400 processes the information received from information collectors 401 , and provides real time, though not necessarily instantaneous, output control signals to controlled equipment 402 .
- the information collectors 401 can include, for example, the components illustrated at 38 and 40 in FIG. 4 .
- the controlled equipment 402 can include, for example, control valves such as illustrated at 37 in FIG. 4 .
- the controller 400 includes information (for example, data and program) storage and an information processor (CPU).
- the information storage can include a database for storing information received from the information collectors 401 .
- the information processor is interconnected with the information storage such that controller 400 is capable, for example, of implementing the functions illustrated at 32 - 36 in FIG. 4 .
- controller 400 is capable, for example, of implementing the functions illustrated at 32 - 36 in FIG. 4 .
- operation of the controlled equipment 402 affects conditions 404 (for example, wellbore conditions) which are monitored by the information collectors 401 .
- FIG. 5 illustrates exemplary operations which can be performed by the controller 400 of FIG. 4A to implement the data management function 32 of FIG. 4 .
- the production/injection (P/I) data both measured (for example, from box 38 of FIG. 4 ) and simulated (for example, output from box 33 of FIG. 4 ) is monitored in real time. Any variances in the P/I data are detected at 52 . If variances are detected at 52 , then at 53 , the new P/I data is updated in real time to the Nodal Analysis and Material Balance functions 34 and 35 of FIG. 4 .
- geologic data for example, from box 40 of FIG. 4 , is monitored in real time. If any changes in the geologic data are detected at 55 , then at 56 , the new geologic data is updated in real time to the Reservoir Simulation function 33 of FIG. 4 .
- FIG. 6 illustrates exemplary operations which can be performed by the controller 400 of FIG. 4A to implement the Nodal Analysis function 35 and the Material Balance function 34 of FIG. 4 .
- the controller monitors for real time updates of the P/I data from the data management function 32 . If any update is detected at 62 , then conventional Nodal Analysis and Material Balance functions are performed at. 63 using the real time updated P/I data. At 64 , new parameters produced at 63 are updated in real time to the Reservoir Simulation function 33 .
- FIG. 7 illustrates exemplary operations which can be performed by the controller 400 of FIG. 4A to implement the Reservoir Simulation function 33 of FIG. 4 .
- the controller 400 monitors for a real time update of geologic data from the data management function 32 or for a real time update of parameters output from either the Nodal Analysis function 35 or the Material Balance function 34 in FIG. 4 . If any of the aforementioned updates are detected at 72 , then the updated information is used in conventional fashion at 73 to produce a new simulation forecast.
- the new simulation forecast is compared to a forecast history (for example, a plurality of earlier simulation forecasts) and, if the new simulation is acceptable at 75 in view of the forecast history, then at 76 the new forecast is updated in real time to the Risked Economics function 36 of FIG. 4 .
- a forecast history for example, a plurality of earlier simulation forecasts
- a new forecast could be rejected, for example, if it is considered to be too dissimilar from one or more earlier forecasts in the forecast history. If the new forecast is rejected at 75 , then either another forecast is produced using the same updated information (see broken line at 78 ), or another real time update of the input information is awaited at 71 .
- the broken line at 77 further indicates that the comparison and decision steps at 74 and 75 can be omitted as desired in some embodiments.
- FIG. 8 illustrates exemplary operations which can be performed by the controller 400 of FIG. 4A to implement the Risked Economics function 36 of FIG. 4 .
- the controller monitors for a real time update of the simulation forecast from the Reservoir Simulation function 33 of FIG. 4 . If any update is detected at 82 , then the new forecast is used in conventional fashion to produce new best case settings for the controlled equipment 402 . Thereafter at 84 , equipment control signals such as illustrated at 50 in FIG. 4 are produced in real time based on the new best case settings.
- Table 1 includes a suite of tools (computer programs) that seamlessly interface with each other to generate a field wide production/injection forecast that is used to control production and injection in wells on a real time basis.
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Abstract
Description
TABLE 1 | ||||
Computer | ||||
Program | Source of | |||
(Commercial | Program | |||
Flow Chart | Name or | (name of | ||
Number | Input Data | Output Data | Data Source) | company) |
1. Downhole | Pressure, | Annulus | ||
Prod. (across | temp, flow | (between | ||
reservoir | rates | tubing and | ||
interval) | casing) | |||
annular and | ||||
tubing | ||||
pressure | ||||
(psi), temp | ||||
(degrees, | ||||
Fahrenheit, | ||||
Centigrade), | ||||
|
||||
2. Seabed prod. | Pressure, | Pressure, | ||
(at subsea tree | temp, flow | temperature | ||
& subsea | rates | |||
manifold) | ||||
3. Surface | Pressure, | Pressure, | ||
prod. (at | temp, flow | temperature | ||
separators, | rates | |||
compressors, | ||||
manifolds, | ||||
other surface | ||||
equipment) | ||||
4. Pressure | Pressure, | Reservoir | Saphir | Kappa |
Transient | temp, flow | Permeability | Engineering | |
Analysis | rates | Reservoir | PTA | Geographix |
Pressure, | ||||
Skin, | ||||
distance to | ||||
boundaries | ||||
5. Logs, Cores, | Pressure, | |||
| temperature | |||
6. Log | Saturations | Petroworks | Landmark | |
processing | Porosity | Graphics | ||
(interpretation) | Clay Content | Prizm | | |
DPP | Halliburton | |||
6A. | Stratworks | | ||
Stratigraphy | Graphics | |||
6B. Mapping | Z-Map | Landmark | ||
Graphics | ||||
7. |
||||
8. Seismic | Hydrocarbon | Seisworks | Landmark | |
Processing and | indicators | Earthcube | Graphics | |
| Stratigraphy | |||
Structure | ||||
9. | Sigmaview | | ||
Geostatistics | Graphics | |||
10. Geocellular | | Landmark | ||
Graphics | ||||
11. Upscaling | Geolink | Landmark | ||
Graphics | ||||
Geoquest | ||||
12. Data | Outputs from | Finder | Landmark | |
Management, | other boxes | Open worker | Graphics | |
Data | Open/ | |||
Repository | Explore | |||
TOW/cs | ||||
DSS32 | ||||
13. Reservoir | Field or well | VIP | Landmark | |
simulation | production | Graphics | ||
profile with | | Geoquest | ||
time | ||||
14. Material | Fluid | Hydro- | MBAL | |
Balance | Saturations, | carbon, in- | ||
Pressure | place reser- | |||
reservoir | voir drive | |||
geometry, | mechanism, | |||
temp, fluid | production | |||
physical | profile | |||
prop., flow | ||||
rate, reser- | ||||
voir | ||||
properties | ||||
15. Nodal | Wellbore | Rate vs. | WEM | P. E. |
Analysis, | configura- | Pressure for | Moseley & | |
Reservoir and | tions, surface | various | GAP | Associates |
Fluid | facility | system and | Prosper | Petroleum |
properties | configura- | constraints | Openflow | Experts |
tions | |
|||
16. Risked | Product | Rate of re- | Aries | Landmark |
Economics | Price Fore- | turn, net | ResEV | Graphics |
cast, Reve- | present | |||
nue Working | value, pay- | |||
Interest, Dis- | out, profit | |||
count Rate, | vs. invest- | |||
Production | ment ratio | |||
Profile, Cap- | and desired | |||
ital Expense, | field wide | |||
Operating | production | |||
Expense | rates. | |||
17. Control | Geometry | |||
Production | ||||
Claims (85)
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US6853921B2 (en) | 2005-02-08 |
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US7079952B2 (en) | 2006-07-18 |
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