|Publication number||USRE41999 E1|
|Application number||US 11/704,369|
|Publication date||14 Dec 2010|
|Priority date||20 Jul 1999|
|Also published as||US6853921, US7079952, US20020099505, US20050038603, USRE42245|
|Publication number||11704369, 704369, US RE41999 E1, US RE41999E1, US-E1-RE41999, USRE41999 E1, USRE41999E1|
|Inventors||Jacob Thomas, Craig William Godfrey, William Launey Vidrine, Jerry Wayne Wauters, Douglas Donald Seller|
|Original Assignee||Halliburton Energy Services, Inc.|
|Export Citation||BiBTeX, EndNote, RefMan|
|Patent Citations (125), Non-Patent Citations (80), Referenced by (2), Classifications (8), Legal Events (1)|
|External Links: USPTO, USPTO Assignment, Espacenet|
The present application is a continuation of U.S. patent application Ser. No. 09/976,573, filed Oct. 12, 2001 now U.S. Pat. No. 6,853,921 which is a continuation-in-part of U.S patent application Ser. No. 09/816,044 now U.S. Pat. No. 6,356,844, filed Mar. 23, 2001 which is a continuation of Ser. No. 09/357,426 now U.S. Pat. No. 6,266,619, filed Jul. 20, 1999, all of which are hereby incorporated by reference in their entirety as if reproduced herein.
Reissue application Ser. No. 12/436,632 is a divisional of this reissue application Ser. No. 11/704,369.
Historically, most oil and gas reservoirs have been developed and managed under timetables and scenarios as follows: a preliminary investigation of an area was conducted using broad geological methods for collection and analysis of data such as seismic, gravimetric, and magnetic data, to determine regional geology and subsurface reservoir structure. In some instances, more detailed seismic mapping of a specific structure was conducted in an effort to reduce the high cost, and the high risk, of an exploration well. A test well was then drilled to penetrate the identified structure to confirm the presence of hydrocarbons, and to test productivity. In lower-cost onshore areas, development of a field would commence immediately by completing the test well as a production well. In higher cost or more hostile environments such as the North Sea, a period of appraisal would follow, leading to a decision as to whether or not to develop the project. In either case, based on inevitably sparse data, further development wells, both producers and injectors would be planned in accordance with a reservoir development plan. Once production and/or injection began, 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. As more data became available, 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.
Limited and relatively poor quality of reservoir data throughout the life of the reservoir, coupled with the relatively high cost of most types of well intervention, implies that reservoir management is as much an art as a science. Engineers and geoscientists responsible for reservoir management discussed injection water, fingering, oil-water contacts rising, and fluids moving as if these were a precise process. The reality, however, is that water expected to take three years to break through to a producing well might arrive in six months in one reservoir but might never appear in another. Text book “piston like” displacement rarely happens, and one could only guess at flood patterns.
For some time, reservoir engineers and geoscientists have made assessments of reservoir characteristics and optimized production using down hole test data taken at selected intervals. Such 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.
Recent improvements in the state of the art regarding data gathering, both down hole and at the surface, have dramatically increased the quantity and quality of data gathered. Examples of such state of the art improvements in data acquisition technology include assemblies run in the casing string comprising a sensor probe with optional flow ports that allow fluid inflow from the formation into the casing while sensing wellbore and/or reservoir characteristics as described and disclosed in international PCT application WO. 97/49894, assigned to Baker Hughes, the disclosure of which is incorporated herein by reference. The casing assembly may further include a microprocessor, a transmitting device, and a controlling device located in the casing string for processing and transmitting real time data. A memory device may also be provided for recording data relating to the monitored wellbore or reservoir characteristics. Examples of 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. Using a microprocessor, 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.
Recent technology improvements in downhole flow control devices are disclosed in UK Patent Application GB 2,320,731A which describes a number of downhole flow control devices which may be used to shut off particular zones by using downhole electronics and programing with decision making capacity, the disclosure of which is incorporated by reference.
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. In the past, seismic surveys were conducted only for exploration purposes. However, 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. By using 4-D seismic processing, reservoir engineers can locate bypassed oil to optimize infill drilling and flood pattern. Additionally, 4-D seismic processing can be used to enhance the reservoir model and history match flow simulations.
International PCT application WO 98/07049, assigned to Geo-Services, the disclosure of which is incorporated herein by reference, describes and discloses state of the art seismic technology applicable for gathering data relevant to a producing reservoir. The publication discloses 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.
Historically, down hole data and surface production data has been analyzed by pressure transient and production analysis. Presently, a number of commercially available computer programs such as Saphir and PTA are available to do such an analysis. The pressure transient analysis generates output data well known in the art, such as permeability-feet, skin, average reservoir pressure and the estimated reservoir boundaries. Such reservoir parameters may be used in the reservoir management system of the present invention.
In the past and present, 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.
Presently, 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. Once the field wide production has been forecasted, selected wells may be produced at selected rates to obtain the selected forecast rate. Likewise, such analysis is used to determine field wide injection rates for maintenance of reservoir pressure and for water flood pattern development. In a similar manner, target injection rates and zonal profiles are determined to obtain the field wide injection rates.
It is estimated that between fifty and seventy percent of a reservoir engineer's time is spent manipulating data for use by each of the computer programs in order for the data gathered and processed by the disparate programs (developed by different companies) to obtain a resultant output desired field wide production forecast. Due to the complexity and time required to perform these functions, frequently an abbreviated incomplete analysis is performed with the output used to adjust a surface choke or recomplete a well for better reservoir performance without knowledge of how such adjustment will affect reservoir management as a whole.
The present invention comprises a field wide management system for a petroleum reservoir on a real time basis. Such 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.
The disclosed invention will be described with reference to the accompanying drawings, which show important sample embodiments of the invention and which are incorporated in the specification hereof by reference. A more complete understanding of the present invention may be had by reference to the following Detailed Description when taken in conjunction with the accompanying drawings, wherein:
Reference is now made to the Drawings wherein like reference characters denote like or similar parts throughout the Figures.
Referring now to
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
Efficient and sophisticated “field wide reservoir data” is necessary for the method and system of real time reservoir management of the present invention. Referring now to blocks 1, 2, 3, 5 and 7 of
In order to provide for more efficient usage of “field wide reservoir data”, the data may be divided into two broad areas: production and/or injection (hereinafter “production/injection”) data and 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.
Referring to box 18, 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.
Referring to box 20, 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 6A by programs such as Stratworks by Landmark Graphics and may be further pre-processed to map the reservoir as noted in block 6B 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 6B 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.
Referring to box 19 of
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. Alternatively, 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.
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. As above, transmission of the real time signal is not necessarily instantaneous, and can be delayed depending on the communication method. For example, 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.
To obtain an improved level of reservoir performance, downhole controls are necessary to enable reservoir engineers to control the reservoir response much like a process engineer controls a process facility. State of the art sensor and control technology now make it realistic to consider systematic development of a reservoir much as one would develop and control a process plant. An example of state of the art computers and plant process control is described in PCT application WO 98/37465 assigned to Baker Hughes Incorporated.
In the system and method of real time reservoir management of the present invention, 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. Within the wellbore, 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. Between zonal isolation packers, variable chokes may be used to regulate the flow of fluids into or out of the reservoir management interval.
U.S. Pat. No. 5,547,029 by Rubbo, the disclosure of which is incorporated by reference, discloses a controlled reservoir analysis and management system that illustrates equipment and systems that are known in the art and may be used in the practice of the present invention. Referring now to
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. As discussed in the background section, 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.
As illustrated in
(a) one or more 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;
(b) 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;
(c) 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;
(d) 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.
(e) 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.
A typical flow control apparatus for use in a subterranean well that is compatible with the SCRAMSJ system is illustrated and described in pending U.S. patent application Ser. No. 08/898,567 filed Jul. 21, 1997 by inventor Brett W. Boundin, the disclosure of which is incorporated by reference.
Referring now to blocks 21, 22, 23 of
Referring to box 38, in the system of the present invention, 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.
Referring to box 40, 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 26A by programs such as Stratworks by Landmark Graphics and may be further pre-processed to map the reservoir as noted in block 26B 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 26B 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.
Referring to box 39 of
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. 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
Referring to the comparison and decision at 74 and 75, 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.
The following 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.
2. Seabed prod.
(at subsea tree
5. Logs, Cores,
7. Seismic Data
Field or well
Rate of re-
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, or any of the aforementioned programs. These programs are merely examples of presently available programs which can be suitably enhanced for real time operations, and used to practice the invention.
It will be understood by those skilled in the art that the method and system of reservoir management may be used to optimize development of a newly discovered reservoir and is not limited to utility with previously developed reservoirs.
A preferred embodiment of the invention has been illustrated in the accompanying Drawings and described in the foregoing Detailed Description, it will be understood that the invention is not limited to the embodiment disclosed, but is capable of numerous modifications without departing from the scope of the invention as claimed.
|Cited Patent||Filing date||Publication date||Applicant||Title|
|US3045750||22 Jan 1957||24 Jul 1962||Us Industries Inc||Control systems|
|US3760362||19 Oct 1971||18 Sep 1973||Halliburton Co||Oil field production automation method and apparatus|
|US3971926||28 May 1975||27 Jul 1976||Halliburton Company||Simulator for an oil well circulation system|
|US4461172||24 May 1982||24 Jul 1984||Inc. In-Situ||Well monitoring, controlling and data reducing system|
|US4559610||4 May 1983||17 Dec 1985||Southwest Research Corporation||Gas pumping system analog|
|US4633954||5 Dec 1983||6 Jan 1987||Otis Engineering Corporation||Well production controller system|
|US4676313||30 Oct 1985||30 Jun 1987||Rinaldi Roger E||Controlled reservoir production|
|US4685522||30 Jun 1986||11 Aug 1987||Otis Engineering Corporation||Well production controller system|
|US4721158||15 Aug 1986||26 Jan 1988||Amoco Corporation||Fluid injection control system|
|US4738313||20 Feb 1987||19 Apr 1988||Delta-X Corporation||Gas lift optimization|
|US5208748||19 Jun 1989||4 May 1993||Action Technologies, Inc.||Method and apparatus for structuring and managing human communications by explicitly defining the types of communications permitted between participants|
|US5442730||8 Oct 1993||15 Aug 1995||International Business Machines Corporation||Adaptive job scheduling using neural network priority functions|
|US5455780||25 Feb 1994||3 Oct 1995||Halliburton Company||Method of tracking material in a well|
|US5531270||4 May 1995||2 Jul 1996||Atlantic Richfield Company||Downhole flow control in multiple wells|
|US5547029||27 Sep 1994||20 Aug 1996||Rubbo; Richard P.||Surface controlled reservoir analysis and management system|
|US5565862||28 Mar 1995||15 Oct 1996||The Titan Corporation||Collection and management of pipeline-flow data|
|US5566092||30 Dec 1993||15 Oct 1996||Caterpillar Inc.||Machine fault diagnostics system and method|
|US5597042||9 Feb 1995||28 Jan 1997||Baker Hughes Incorporated||Method for controlling production wells having permanent downhole formation evaluation sensors|
|US5636693||20 Dec 1994||10 Jun 1997||Conoco Inc.||Gas well tubing flow rate control|
|US5662165||12 Aug 1996||2 Sep 1997||Baker Hughes Incorporated||Production wells having permanent downhole formation evaluation sensors|
|US5706896||9 Feb 1995||13 Jan 1998||Baker Hughes Incorporated||Method and apparatus for the remote control and monitoring of production wells|
|US5710726||10 Oct 1995||20 Jan 1998||Atlantic Richfield Company||Semi-compositional simulation of hydrocarbon reservoirs|
|US5721538||13 Aug 1996||24 Feb 1998||Baker Hughes Incorporated||System and method of communicating between a plurality of completed zones in one or more production wells|
|US5730219||11 Sep 1995||24 Mar 1998||Baker Hughes Incorporated||Production wells having permanent downhole formation evaluation sensors|
|US5732776||9 Feb 1995||31 Mar 1998||Baker Hughes Incorporated||Downhole production well control system and method|
|US5764515||13 May 1996||9 Jun 1998||Institute Francais Du Petrole||Method for predicting, by means of an inversion technique, the evolution of the production of an underground reservoir|
|US5767680||11 Jun 1996||16 Jun 1998||Schlumberger Technology Corporation||Method for sensing and estimating the shape and location of oil-water interfaces in a well|
|US5829520||24 Jun 1996||3 Nov 1998||Baker Hughes Incorporated||Method and apparatus for testing, completion and/or maintaining wellbores using a sensor device|
|US5841678||17 Jan 1997||24 Nov 1998||Phillips Petroleum Company||Modeling and simulation of a reaction for hydrotreating hydrocarbon oil|
|US5842149||22 Oct 1996||24 Nov 1998||Baker Hughes Incorporated||Closed loop drilling system|
|US5859437||17 Mar 1997||12 Jan 1999||Taiwan Semiconductor Manufacturing Corporation||Intelligent supervision system with expert system for ion implantation process|
|US5871047||12 Aug 1997||16 Feb 1999||Schlumberger Technology Corporation||Method for determining well productivity using automatic downtime data|
|US5873049||21 Feb 1997||16 Feb 1999||Atlantic Richfield Company||Abstraction of multiple-format geological and geophysical data for oil and gas exploration and production analysis|
|US5881811||20 Dec 1996||16 Mar 1999||Institut Francais Du Petrole||Modeling of interactions between wells based on produced watercut|
|US5959547||17 Sep 1997||28 Sep 1999||Baker Hughes Incorporated||Well control systems employing downhole network|
|US5975204||26 Sep 1997||2 Nov 1999||Baker Hughes Incorporated||Method and apparatus for the remote control and monitoring of production wells|
|US5979558||21 Jul 1997||9 Nov 1999||Bouldin; Brett Wayne||Variable choke for use in a subterranean well|
|US5992519||29 Sep 1997||30 Nov 1999||Schlumberger Technology Corporation||Real time monitoring and control of downhole reservoirs|
|US6002985||6 May 1997||14 Dec 1999||Halliburton Energy Services, Inc.||Method of controlling development of an oil or gas reservoir|
|US6021377||23 Oct 1996||1 Feb 2000||Baker Hughes Incorporated||Drilling system utilizing downhole dysfunctions for determining corrective actions and simulating drilling conditions|
|US6021662||5 Oct 1998||8 Feb 2000||Institut Francais Du Petrole||Method for modeling fluid displacements in a porous medium|
|US6022985||7 Jul 1995||8 Feb 2000||Rhone-Poulenc Rorer S.A.||Process for the preparation of 4-acetoxy-2α-benzoyloxy-5β, 20-epoxy-1, 7β-10β-trihydroxy-9-oxo-tax-11-en-13α-yl(2R,3S)-3-tert-b utoxy-carbonYlamino-2-hydroxy-3-phenylpropionate trihydrate|
|US6023656||30 Dec 1997||8 Feb 2000||Institut Francais Du Petrole||Method for determining the equivalent fracture permeability of a fracture network in a subsurface multi-layered medium|
|US6076046||24 Jul 1998||13 Jun 2000||Schlumberger Technology Corporation||Post-closure analysis in hydraulic fracturing|
|US6095262||31 Aug 1999||1 Aug 2000||Halliburton Energy Services, Inc.||Roller-cone bits, systems, drilling methods, and design methods with optimization of tooth orientation|
|US6098020||8 Apr 1998||1 Aug 2000||Shell Oil Company||Downhole monitoring method and device|
|US6101447||12 Feb 1998||8 Aug 2000||Schlumberger Technology Corporation||Oil and gas reservoir production analysis apparatus and method|
|US6112126||20 Feb 1998||29 Aug 2000||Baker Hughes Incorporated||Adaptive object-oriented optimization software system|
|US6112817||6 May 1998||5 Sep 2000||Baker Hughes Incorporated||Flow control apparatus and methods|
|US6176323||26 Jun 1998||23 Jan 2001||Baker Hughes Incorporated||Drilling systems with sensors for determining properties of drilling fluid downhole|
|US6182756||10 Feb 1999||6 Feb 2001||Intevep, S.A.||Method and apparatus for optimizing production from a gas lift well|
|US6192980||7 Jan 1998||27 Feb 2001||Baker Hughes Incorporated||Method and apparatus for the remote control and monitoring of production wells|
|US6236894||19 Dec 1997||22 May 2001||Atlantic Richfield Company||Petroleum production optimization utilizing adaptive network and genetic algorithm techniques|
|US6266619||20 Jul 1999||24 Jul 2001||Halliburton Energy Services, Inc.||System and method for real time reservoir management|
|US6281489||1 May 1998||28 Aug 2001||Baker Hughes Incorporated||Monitoring of downhole parameters and tools utilizing fiber optics|
|US6282452||19 Nov 1998||28 Aug 2001||Intelligent Inspection Corporation||Apparatus and method for well management|
|US6356844||23 Mar 2001||12 Mar 2002||Halliburton Energy Services, Inc.||System and method for real time reservoir management|
|US6397946||19 Jan 2000||4 Jun 2002||Smart Drilling And Completion, Inc.||Closed-loop system to compete oil and gas wells closed-loop system to complete oil and gas wells c|
|US6412555||4 Jun 1999||2 Jul 2002||Kongsberg Offshore A.S.||System and method for controlling fluid flow in one or more oil and/or gas wells|
|US6422312||13 Oct 1999||23 Jul 2002||Retrievable Information Systems, Llc||Multizone production monitoring system|
|US6424919||26 Jun 2000||23 Jul 2002||Smith International, Inc.||Method for determining preferred drill bit design parameters and drilling parameters using a trained artificial neural network, and methods for training the artificial neural network|
|US6434435||14 May 1999||13 Aug 2002||Baker Hughes Incorporated||Application of adaptive object-oriented optimization software to an automatic optimization oilfield hydrocarbon production management system|
|US6442445||19 Mar 1999||27 Aug 2002||International Business Machines Corporation,||User configurable multivariate time series reduction tool control method|
|US6516293||13 Mar 2000||4 Feb 2003||Smith International, Inc.||Method for simulating drilling of roller cone bits and its application to roller cone bit design and performance|
|US6549879||21 Sep 1999||15 Apr 2003||Mobil Oil Corporation||Determining optimal well locations from a 3D reservoir model|
|US6584368||17 Sep 2002||24 Jun 2003||International Business Machines Corporation||User configurable multivariate time series reduction tool control method|
|US6609079||6 May 1999||19 Aug 2003||Va Tech Elin Transformatoren Gmbh||Method and arrangement for ascertaining state variables|
|US6678569||6 Nov 2001||13 Jan 2004||International Business Machines Corporation||User configurable multivariate time series reduction tool control method|
|US6701514||27 Mar 2000||2 Mar 2004||Accenture Llp||System, method, and article of manufacture for test maintenance in an automated scripting framework|
|US6823296||21 Dec 2001||23 Nov 2004||Institut Francais Du Petrole||Method for forming an optimized neural network module intended to simulate the flow mode of a multiphase fluid stream|
|US6826483||13 Oct 2000||30 Nov 2004||The Trustees Of Columbia University In The City Of New York||Petroleum reservoir simulation and characterization system and method|
|US6853921||12 Oct 2001||8 Feb 2005||Halliburton Energy Services, Inc.||System and method for real time reservoir management|
|US6871118||25 Feb 2002||22 Mar 2005||Institut Francais Du Petrole||Method for detecting and controlling hydrate formation at any point of a pipe carrying multiphase petroleum fluids|
|US6954737||5 Nov 2001||11 Oct 2005||Johnsondiversey, Inc.||Method and apparatus for work management for facility maintenance|
|US6980940||12 Sep 2000||27 Dec 2005||Schlumberger Technology Corp.||Intergrated reservoir optimization|
|US6985750||26 Apr 2000||10 Jan 2006||Bj Services Company||Wireless network system|
|US7047170||13 Apr 2001||16 May 2006||Lockheed Martin Corp.||Method of determining boundary interface changes in a natural resource deposit|
|US7054752||2 Jun 2004||30 May 2006||Institut Francais Du Petrole||Method for optimizing production of an oil reservoir in the presence of uncertainties|
|US7062420||28 Sep 2001||13 Jun 2006||Schlumberger Technology Corp.||Production optimization methodology for multilayer commingled reservoirs using commingled reservoir production performance data and production logging information|
|US7072809||10 Jul 2001||4 Jul 2006||Gaz De France||Method for modelling fluid displacements in a porous environment taking into account hysteresis effects|
|US7079952||30 Aug 2004||18 Jul 2006||Halliburton Energy Services, Inc.||System and method for real time reservoir management|
|US7096092||3 Nov 2000||22 Aug 2006||Schlumberger Technology Corporation||Methods and apparatus for remote real time oil field management|
|US7266456||19 Apr 2005||4 Sep 2007||Intelligent Agent Corporation||Method for management of multiple wells in a reservoir|
|US7277836||6 Dec 2001||2 Oct 2007||Exxonmobil Upstream Research Company||Computer system and method having a facility network architecture|
|US7373976||18 Nov 2004||20 May 2008||Casey Danny M||Well production optimizing system|
|US20020049625||11 Sep 2001||25 Apr 2002||Srinivas Kilambi||Artificial intelligence manufacturing and design|
|US20030028325||18 Apr 2002||6 Feb 2003||Frederic Roggero||Method of constraining by dynamic production data a fine model representative of the distribution in the reservoir of a physical quantity characteristic of the subsoil structure|
|US20030139916||18 Jan 2002||24 Jul 2003||Jonggeun Choe||Method for simulating subsea mudlift drilling and well control operations|
|US20030167157||3 Mar 2003||4 Sep 2003||Pascal Mougin||Method for modelling asphaltenes flocculation conditions in hydrocarbon-containing fluids related to a reference fluid|
|US20040104027||4 Feb 2002||3 Jun 2004||Rossi David J.||Optimization of reservoir, well and surface network systems|
|US20040138862||30 Oct 2003||15 Jul 2004||Lin-Ying Hu||Method for rapid formation of a stochastic model representative of a heterogeneous underground reservoir, constrained by dynamic data|
|US20040148147||24 Jan 2003||29 Jul 2004||Martin Gregory D.||Modeling in-situ reservoirs with derivative constraints|
|US20040153437||31 Dec 2003||5 Aug 2004||Buchan John Gibb||Support apparatus, method and system for real time operations and maintenance|
|US20040220790||3 Sep 2003||4 Nov 2004||Cullick Alvin Stanley||Method and system for scenario and case decision management|
|US20040230413||4 Feb 2004||18 Nov 2004||Shilin Chen||Roller cone bit design using multi-objective optimization|
|US20040236553||4 Feb 2004||25 Nov 2004||Shilin Chen||Three-dimensional tooth orientation for roller cone bits|
|US20050010384||10 May 2004||13 Jan 2005||The University Of Tokyo||Method of simulating fluctuation of oil, program of the same and system of the same|
|US20050096893||2 Jun 2004||5 May 2005||Mathieu Feraille||Decision support method for oil reservoir management in the presence of uncertain technical and economic parameters|
|US20050149307||2 Mar 2005||7 Jul 2005||Schlumberger Technology Corporation||Integrated reservoir optimization|
|US20050267718||25 May 2004||1 Dec 2005||Chevron U.S.A. Inc.||Method for field scale production optimization by enhancing the allocation of well flow rates|
|US20050267771||27 May 2004||1 Dec 2005||Biondi Mitchell J||Apparatus, system and method for integrated lifecycle management of a facility|
|US20050273301||31 Mar 2005||8 Dec 2005||Smith International, Inc.||Techniques for modeling/simulating, designing optimizing, and displaying hybrid drill bits|
|US20050273303||23 May 2005||8 Dec 2005||Nicolas Flandrin||Method of generating a conforming hybrid grid in three dimensions of a heterogeneous formation crossed by one or more geometric discontinuities in order to carry out simulations|
|US20060085174||15 Oct 2004||20 Apr 2006||Kesavalu Hemanthkumar||Generalized well management in parallel reservoir simulation|
|US20060116856||1 Dec 2005||1 Jun 2006||Webb Robert A||Application of phase behavior models in production allocation systems|
|US20060149520||18 Feb 2004||6 Jul 2006||Mickaele Le Ravalec-Dupin||Method for more rapidly producing the representative stochastic model of a heterogeneous underground reservoir defined by uncertain static and dynamic data|
|US20070078637||30 Sep 2005||5 Apr 2007||Berwanger, Inc.||Method of analyzing oil and gas production project|
|US20070112547||23 Nov 2002||17 May 2007||Kassem Ghorayeb||Method and system for integrated reservoir and surface facility networks simulations|
|US20070179766||31 Jan 2007||2 Aug 2007||Landmark Graphics Corporation||Methods, systems, and computer-readable media for real-time oil and gas field production optimization using a proxy simulator|
|US20070179767||31 Jan 2007||2 Aug 2007||Alvin Stanley Cullick||Methods, systems, and computer-readable media for fast updating of oil and gas field production models with physical and proxy simulators|
|US20070179768||31 Jan 2007||2 Aug 2007||Cullick Alvin S||Methods, systems, and computer readable media for fast updating of oil and gas field production models with physical and proxy simulators|
|US20070192072||31 Jan 2007||16 Aug 2007||Cullick Alvin S||Methods, systems, and computer-readable media for real-time oil and gas field production optimization using a proxy simulator|
|US20070198223||19 Jan 2007||23 Aug 2007||Ella Richard G||Dynamic Production System Management|
|US20070271039||19 Jan 2007||22 Nov 2007||Ella Richard G||Dynamic Production System Management|
|US20070295501||1 Nov 2005||27 Dec 2007||Henk Nico Jan Poulisse||Method and System for Production Metering of Oil Wells|
|US20080133550||15 Aug 2006||5 Jun 2008||The University Of Southern California||Method and system for integrated asset management utilizing multi-level modeling of oil field assets|
|EP1679424A2||14 Feb 2001||12 Jul 2006||Schlumberger Technology Corporation||Integrated reservoir optimization|
|GB2320731B||Title not available|
|WO2002054332A1||11 Dec 2001||11 Jul 2002||Exxonmobil Upstream Research Company||Object-oriented hydrocarbon reservoir system simulation|
|WO2002063130A1||4 Feb 2002||15 Aug 2002||Schlumberger Holdings Limited||Optimization of reservoir, well and surface network systems|
|WO2002063403A2||30 Jan 2002||15 Aug 2002||Fisher Controls International Llc||Reporting regulator for managing a gas transportation system|
|WO2002101555A2||3 Jun 2002||19 Dec 2002||Honeywell International Inc.||Adaptive knowledge management system for vehicle trend monitoring, health management and preventive maintenance|
|WO2004049216A1||23 Nov 2002||10 Jun 2004||Schlumberger Technology Corporation||Method and system for integrated reservoir and surface facility networks simulations|
|WO2004079144A2||18 Feb 2004||16 Sep 2004||Institut Francais Du Petrole||Method for more rapidly producing the representative stochastic model of a heterogeneous underground reservoir defined by uncertain static and dynamic data|
|WO2004095259A1||16 Mar 2004||4 Nov 2004||Exxonmobil Upstream Research Company||Performance prediction method for hydrocarbon recovery processes|
|1||Ajayi, et al., "A Dynamic Optimisation Technique for Simulation of Multi-Zone Intelligent Well Systems in a Reservoir Development", SPE 84192 Society of Petroleum Engineers, Copyright 2003, pp. 1-7 (7 pages).|
|2||Allard et al., "Reservoir Management Making A Difference In Australia's First Oilfield Developed Entirely With Horizontal Wells", paper SPE 50051, SPE Asia Specific Oil & Gas Conf., Oct. 12-14, 1998, pp. 165-173 (9 pages).|
|3||Aminian, K., Ameri, S., "Application of artificial neural networks for reservoir characterization with limited data", Journal of Petroleum Science and Engineering 49, pp. 212-222, May 20, 2005.|
|4||Barroux, C.C., et al., "Linking Reservoir and Surface Simulators: How to Improve the Coupled Solutions," Society of Petroleum Engineers, SPE 65159, Copyright 2000, Abstract Only, 2 pages.|
|5||Beamer et al., "From Pore To Pipeline, Field Scale Solutions"; Oilfield Review, vol. 10, No. 2, 1998, XP000961345, pp. 2-19 (18 pages).|
|6||Beliakova, N., et al., "Hydrocarbon Field Planning Tool for Medium to Long Term Production Forecasting from Oil and Gas Fields Using Integrated Subsurface-Surface Models," Society of Petroleum Engineers, SPE 65160, Copyright 2000, 5 pages.|
|7||Beliakova, N., et al., "Hydrocarbon Field Planning Tool for Medium to Long Term Production Forecasting from Oil and Gas Fields Using Integrated Subsurface—Surface Models," Society of Petroleum Engineers, SPE 65160, Copyright 2000, 5 pages.|
|8||Bogaert, et al., "Improving Oil Production Using Smart Fields Technology in the SF30 Satellite Oil Development Offshore Malaysia," OTC 16162, Offshore Technology Conference, Copyright 2004, pp. 1-7 (7 pages).|
|9||Brochure, Landmark: A Halliburton Company, Corporate Data Archiver(TM), Copyright 2003, 4 pages.|
|10||Brochure, Landmark: A Halliburton Company, Corporate Data Archiver™, Copyright 2003, 4 pages.|
|11||Bruheim, Bjarte, "Data Management-A Key to Cost Effective B&P", Offshore, Dec. 1987.|
|12||Bruheim, Bjarte, "Data Management—A Key to Cost Effective B&P", Offshore, Dec. 1987.|
|13||Bruni, et al., "A Technically Rigorous and Fully Automated System for Performance Monitoring and Production Test Validation ", SPE 84881, Society of Petroleum Engineers, Copyright 2003, pp. 1-10 (10 pages).|
|14||Caers, Jef, "Efficient gradual deformation using a streamline-based proxy method", Journal of Petroleum Science and Engineering 39 (2003), pp. 57-83.|
|15||Centilmen, A., Ertekin, T., Grader, A.S., "Applications of Neural Networks in Multiwell Field Development", SPE 56443, prepared for presentation at the 1999 SPE Annual Technical Conference and Exhibition, Houston, Texas, Oct. 3-6, 1999.|
|16||Clark E. Robison, "Overcoming the Challenges Associated With the Life-Cycle Management of Multilateral Wells: Assessing Moves Toward the ‘Intelligent Completion’", SPE 38497, paper prepared for presentation at the 1997 Offshore Europe Conference, Aberdeen, Scotland, Sep. 9-12, 1997, pp. 269-276 (8 pages).|
|17||Clark E. Robison, "Overcoming the Challenges Associated With the Life-Cycle Management of Multilateral Wells: Assessing Moves Toward the 'Intelligent Completion'", SPE 38497, paper prepared for presentation at the 1997 Offshore Europe Conference, Aberdeen, Scotland, Sep. 9-12, 1997, pp. 269-276 (8 pages).|
|18||Computer Searching Results, File 351:Derwent WPI 1963-2006/UD=200703, Jan. 2008, 10 pages.|
|19||Computer Searching Results, File 8:Ei Compendex®, 1970-2007/Dec W5, Jan. 2008, 22 pages.|
|20||Computer Searching Results, Search 1, File 340:Claims®/US Patent 1950-07/Jan 09, Jan. 2008, 12 pages.|
|21||Computer Searching Results, Search 2, File 340:Claims®/US Patent 1950-07/Jan 09, Jan. 2008, 6 pages.|
|22||Cullick, et al., "Optimizing Multiple-Field Scheduling and Production Strategy with Reduced Riski", SPE 84239, Society of Petroleum Engineers, Copyright 2003, pp. 1-12 (12 pages).|
|23||Dashevskiy, D., Dubinsky, V., Macpherson, J.D., "Application of Neural Networks for Predictive Control in Drilling Dynamics", SPE 56442, prepared for presentation at the 1999 SPE Annual Technical Conference and Exhibition, Houston, Texas, Oct. 3-6, 1999.|
|24||David M. Clementz, "Enabling Role of Information Technology: Where are the Limits?", Offshore, Dec. 1987, p. 42 (1 page).|
|25||Deutman, Robert, et al., "A Case Study of Integrated Gas Field System Modelling in the North Sea Environment," Society of Petroleum Engineers, SPE 38556, Copyright 1997, Abstract Only, 2 pages.|
|26||Dick Ghiselin, "New Technology, New Techniques, Set the Pace for Success", Hart's Petroleum Engineer International, Jan. 1998, 2 pages.|
|27||Du, Yupi, Wiess, W. W., Xu, Jianyun, Balch, R.S., Li, Dacun, "Obtain an Optimum Artificial Neural Network Model for Reservoir Studies", SPE 84445, prepared for presentation at the SPE Annual Technical Conference and Exhibition, Denver, Colorado, Oct. 5-8, 2003.|
|28||European Patent Office, Supplementary European Search Report for Application No. EP 04704046.4-2224, dated Oct. 25, 2006 (4 pages).|
|29||G. Botto et al., Snyopsis of "Innovative Remote Controlled Completion for Aquila Deepwater Challenge", JPT, Oct. 1997, originally presented at the 1996 SPE European Petroleum Conference, Milan, Italy, Oct. 22-24, 1996 (3 pages).|
|30||Guyaguler, Baris, Horne, Roland N., Rogers, Leah, Rosenzweig, Jacob J., "Optimization of Well Placement in a Gulf of Mexico Waterflooding Project", SPE 63221, pp. 667-676, prepared for presentation at the 2000 SPE Annual Technical Conference and Exhibition, Dallas, Texas, Oct. 1-4, 2000.|
|31||Halliburton Energy Services, Inc., "SmartWell Technology Asset Management of the Future", Aug. 1998 (6 pages).|
|32||Halliburton, Drilling, Evaluation and Digital Solutions, Landmark, The Role and Development of the Operational Asset Optimization Model Within DecisionSpace for Production Solutions, White Paper, May 2007, 16 pages.|
|33||Haugen, E.D., et al., "Simulation of Independant Reservoirs Couled by Global Production and Injection Constraints," Society of Petroleum Engineers, SPE 29126, Copyright 1995, Abstract Only, 2 pages.|
|34||He, B., Kochhar, A.K., "An expert system for the diagnosis and control of manufacturing processes", International Conference on Computer Aided Production Engineering, Nov. 1988.|
|35||He, Xin-Gui, Xu, Shao-Hua, "Process Neural Network with Time-Varied Input and Output Functions and its Applications," Ruan Jian Xue Bao/Journal of Software, v. 14, n. 4, Apr. 2003, p. 764-769.|
|36||Hepguler, Gokhan, "Integration of a Field Surface and Production Network With a Reservoir Simulator," SPE Computer Applications, vol. 12, No. 4, SPE 38937, Jun. 1997, Abstract Only, 3 pages.|
|37||Ian C. Phillips, "Reservoir Management of the Future", Halliburton M&S Ltd., Aberdeen, Scotland, paper presented at EU Thermie Conference, Apr. 1997, Aberdeen, Scotland, pp. 1-15.|
|38||Johnson, Virginia M., Ammer, James R., Trick, Mona D., "Improving Gas Storage Development Planning Through Simulation-Optimization", SPE 65639, prepared for presentation at the SPE Eastern Regional Meeting, Morgantown, West Virginia, Oct. 17-19, 2000.|
|39||KBR Enterprise-Client RTO Portal, RTO Portal User Manual, Version 1, Dec. 2002, 91 pages.|
|40||KBR Enterprise—Client RTO Portal, RTO Portal User Manual, Version 1, Dec. 2002, 91 pages.|
|41||Ken R. LeSuer, "Breakthrough Productivity-Our Ultimate Challenge", Offshore, Dec. 1987 (1 page).|
|42||Ken R. LeSuer, "Breakthrough Productivity—Our Ultimate Challenge", Offshore, Dec. 1987 (1 page).|
|43||Laplante, Phillip, "It Isn't Your Fathers Realtime Anymore," System Performance, vol. 4, No. 1, Feb. 2006, 3 pages.|
|44||Liao, TonyTianlu, et al., "Evaluating Operation Strategies via Integrated Asset Modeling," Society of Petroleum Engineers, SPE 75525, Copyright 2002, Abstract Only, 2 pages.|
|45||Litvak, et al., "Prudhoe Bay E-Field Production Optimization System Based on Integrated Reservoir and Facility Simulation", SPE 77643, Society of Petroleum Engineers, Copyright 2002, pp. 1-11 (11 pages).|
|46||Litvak, M.L., et al., "Simplified Phase-Equilibrium Calculations in Integrated Reservoir and Surface-Pipeline-Network Models," SPE Journal, vol. 5, No. 2, SPE 64498, Jun. 2000, pp. 236-241, Abstract Only, 3 pages.|
|47||Litvak, M.L., et al., "Surface Network and Well Tubing head Pressure Constraints in Compositional Simulation," Society of Petroleum Engineers, SPE 29125, Copyright 1995, Abstract Only, 2 pages.|
|48||Lobato-Barradas, Gerardo, et al., "Integrated Compositional Surface-Subsurface Modeling for Rate Allocation Calculations," Society of Petroleum Engineers, SPE 74382, Copyright 2002, Abstract Only, 1 page.|
|49||Marsh, Jack, et al., "Wildcat Hills Gas Gathering System Case Studies: An Integrated Approach From Reservoir Development Through to Sales Pipeline Delivery," Society of Petroleum Engineers, SPE 75698, Copyright 2002, 13 pages.|
|50||Mohaghegh, Shahab D., "Recent Developments in Application of Artificial Intelligence in Petroleum Engineering", Journal of Petroleum Technology, v. 57, n. 4, Apr. 2005, pp. 86-91.|
|51||Neupert, Dirk, Schlee, Michael, Simon, Ewald, "MODI-an expert system supporting reliable, economical power plant control", ABB Review, Jan. 1994.|
|52||Neupert, Dirk, Schlee, Michael, Simon, Ewald, "MODI—an expert system supporting reliable, economical power plant control", ABB Review, Jan. 1994.|
|53||Notification of Transmittal of the International Search Report or the Declaration (3 pages) and International Search Report (4 pages) for International Application No. PCT/US 00/19443, dated Nov. 14, 2000.|
|54||Oberwinkler, Christian, Ruthammer, Gerhard, Zangl, Georg, Economides, Michael , "New Tools for Fracture Design Optimization", SPE 86467, prepared for presentation at the SPE International Symposium and Exhibition on Formation Damage Control, Lafayette, Louisiana, Feb. 18-20, 2004.|
|55||Oberwinkler, Christian, Stundner, Michael, "From Real Time Data to Production Optimization", SPE 87008, prepared for presentation at the SPE Asia Pacific Conference on Integrated Modelling for Asset Management, Kuala Lumpur, Malaysia, Mar. 29-30, 2004.|
|56||Pieters, Johan, et al., "Total System Modelling-A Tool for Effective Reservoir Management of Multiple Fields with Shared Facilities," Society of Petroleum Engineers, SPE 30442, Copyright 1995, Abstract Only, 2 pages.|
|57||Pieters, Johan, et al., "Total System Modelling—A Tool for Effective Reservoir Management of Multiple Fields with Shared Facilities," Society of Petroleum Engineers, SPE 30442, Copyright 1995, Abstract Only, 2 pages.|
|58||Remery, George R., "Reshaping Development Opportunities", and Harris, David, "Training and Cooperation Critical to Deepwater Future", Offshore, Dec. 1997, p. 44.|
|59||Rommetveit, Rolv, Vefring, E.H., Wang, Zhihua, Bieseman, Taco, Faure, A.M., "A Dynamic Model for Underbalanced Drilling With Coiled Tubing," SPE/IADC 29363, paper prepared for presentation at the 1995 SPE/IADC Drilling Conference, Drilling Conference, Amsterdam, Feb. 28-Mar. 2, 1995.|
|60||S. Hsieh and C.-C. Chiang, "Manufacturing-to-Sale Planning Model for Fuel Oil Production," The International Journal of Advanced Manufacturing Technology, 2001, 18:303-311.|
|61||Safley et al., "Projects Implement Management Plans", The American Oil & Gas Reporter, vol. 41, No. 9, Sep. 1998, XP000957690, pp. 136, 138-142 (6 pages).|
|62||Sengul, Mahmut, Bekkousha, Miloud A., "Applied Production Optimization: i-Field", SPE 77608, prepared for presentation at the SPE Annual Technical Conference and Exhibition, San Antonio, Texas, Sep. 29-Oct. 2, 2002.|
|63||Sheila Popov, "Two Emerging Technologies Enhance Reservoir Management", Hart's Petroleum Engineer International, Jan. 1998, pp. 43 and 45 (2 pages).|
|64||Smith et al., "The Road Ahead To Real-Time Oil And Gas Reservoir Management", Trans. Inst. Chem. Eng., vol. 76, No. A5, Jul. 1998, XP000957748, 18 pages.|
|65||Stundner, M., Al-Thuwaini, J.S., "How Data-Driven Modeling Methods like Neural Networks can help to integrate different Types of Data into Reservoir Management", SPE 68163, prepared for presentation at the 2001 SPE Middle East Oil Show, Bahrain, Mar. 17-20, 2001.|
|66||Sung, Andrew H., "Applications of soft computing in petroleum engineering", SPE vol. 3812, Part of the SPE Conference on Applications and Science of Neural Networks, Fuzzy Systems, and Evolutionary Computation II, Denver, Colorado, Jul. 1999.|
|67||Thomas R. Bates, Jr., "Technology Pace Must Accelerate to Counter Oilfield Inflation", Offshore, Dec. 1987 (1 page).|
|68||Tingas, John, "Integrated Reservoir and Surface Network Simulation in Reservoir Management of Southern North Sea Gas Reservoirs," Society of Petroleum Engineers, SPE 50635, Copyright 1998, Abstract Only, 2 pages.|
|69||Trick, M.D., "A Different Approach to Coupling a Reservoir Simulatior with a Surface Facilities," Society of Petroleum Engineers, SPE 40001, Copyright 1998, Abstract Only, 1 page.|
|70||Tulsa Petroleum Abstract, Keyword Search Results (Abstract 1-113), 212 pages, various authors and dates.|
|71||U.S. Appl. No. 12/121,710, filed May 15, 2008, entitled "Dynamic Production System Management", inventors Richard G. Ella et al. (continuation of 16689-004001).|
|72||Vinje, "Reservoir Control Using Smart Wells", 10th Underwater Technology Conference Proceedings, Mar. 25-26, 1998, XP000957692, 9 pages.|
|73||Webpage, Landmark: A Halliburton Company, "Calendar of Innovations 2003", Apr. 2003-Decision Space(TM)-Decision Management System, mhtml:file://C:\Documents%20and%20Settings\jyg.FRDOMAIN\Local%20Settings\Tempo..., printed Jun. 6, 2004, 2 pages.|
|74||Webpage, Landmark: A Halliburton Company, "Calendar of Innovations 2003", Apr. 2003—Decision Space™—Decision Management System, mhtml:file://C:\Documents%20and%20Settings\jyg.FRDOMAIN\Local%20Settings\Tempo..., printed Jun. 6, 2004, 2 pages.|
|75||Webpage, Landmark: A Halliburton Company, "Calendar of Innovations 2003", May 2003-Decision Space Asset Planner(TM), mhtml:file://C:\Documents%20and%20Settings\jyg.FRDOMAIN\Local%20Settings\Tempo..., printed Jun. 6, 2004, 2 pages.|
|76||Webpage, Landmark: A Halliburton Company, "Calendar of Innovations 2003", May 2003—Decision Space Asset Planner™, mhtml:file://C:\Documents%20and%20Settings\jyg.FRDOMAIN\Local%20Settings\Tempo..., printed Jun. 6, 2004, 2 pages.|
|77||Weisenborn, A.J. (Toon), et al., "Compositional Integrated Subsurface-Surface Modeling," Society of Petroleum Engineers, SPE 65158, Copyright 2000, Abstract Only, 2 pages.|
|78||Yeten, B., Castellini, A., Guyaguler, B., Chen, W.H., "A Comparison Study on Experimental Design and Response Surface Methodologies", SPE 93347, prepared for presentation at the 2005 SPE Reservoir Simulation Symposium in Houston, Texas, Jan. 31-Feb. 2, 2005.|
|79||Yeten, Burak, Durlofsky, Louis J., Aziz, Khalid, "Optimization of Nonconventional Well Type, Location, and Trajectory", SPE 86880, SPE Journal, Sep. 2003, pp. 200-210.|
|80||Zapata, V.J., et al., "Advances in Tightly Coupled Reservoir/Wellbore/Surface-Network Simulation," SPE Reservoir Evaluation & Engineering, vol. 4, No. 2, SPE 71120, Apr. 2001, pp. 114-120, Abstract Only, 3 pages.|
|Citing Patent||Filing date||Publication date||Applicant||Title|
|US8469090 *||1 Dec 2009||25 Jun 2013||Schlumberger Technology Corporation||Method for monitoring hydrocarbon production|
|US20110127032 *||1 Dec 2009||2 Jun 2011||Schlumberger Technology Corporation||Method for monitoring hydrocarbon production|
|U.S. Classification||702/13, 702/12|
|International Classification||E21B43/12, E21B43/00|
|Cooperative Classification||E21B43/14, E21B43/20|
|European Classification||E21B43/14, E21B43/20|
|14 Sep 2010||AS||Assignment|
Owner name: HALLIBURTON ENERGY SERVICES, INC., TEXAS
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:THOMAS, JACOB;GODFREY, CRAIG WILLIAM;VIDRINE, WILLIAM LAUNEY;AND OTHERS;SIGNING DATES FROM 20011101 TO 20020116;REEL/FRAME:024985/0927
Owner name: HALLIBURTON ENERGY SERVICES, INC., TEXAS
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:THOMAS, JACOB;GODFREY, CRAIG WILLIAM;VIDRINE, WILLIAM LAUNEY;AND OTHERS;SIGNING DATES FROM 20011101 TO 20020116;REEL/FRAME:024985/0927