AndreaBozzo/ceres-open-data-index huggingface dataset:
SIMULATION-ENHANCED FRACTURE DETECTION: RESEARCH AND DEMONSTRATION IN U.S. BASINS

Remote detection and characterization of fractured reservoirs is facilitated in this project by developing a revolutionary software system. The Model-Automated Geo-Informatics (MAGI) software integrates basin modeling, seismic data, synthetic seismic wave propagation and well data via information theory. The result is a seismic inversion cast in terms of fracture and other reservoir characteristics. The MAGI software was fully tested on synthetic data to verify program accuracy and robustness to data error. In Phase II, we (1) collected geological information (stratigraphic, structural, thermal, geochemical, fracturing and other information across the study area) (Task 4.1,4057 ); (2) created a GIS database that is compatible with the input requirements of MAGI (Task 4.1,4057 ); (3) implemented a web-based interface for user friendly access (Task 4.2,4057 ); (4) gathered and preprocessed seismic data for input into MAGI; (5) developed two- and three-dimensional wave propagation simulators (in time domain) for fluid saturated porous media and implemented matching layer methodology for absorbing boundary conditions (Task 4.3,4057 ); (6) developed parallel version of the seismic simulators (Task 4.3,4057 ); (7) proposed an information theory framework that allows for the integration of multiple data types of a range of quality (Task 4.4,4057 ); (8) developed and implemented highly efficient, parallel, Gauss-Newton seismic waveform inversion code based on reciprocity theorem (Task 4.5,4057 ); (9) verified and demonstrated the accuracy and efficiency of the wave propagation and seismic waveform inversion codes (Tasks 4.3 and 4.5,4057 ); and (10) identified the requirements for seismic data to allow seismic inversion (Task 4.6). With these accomplishments, we are prepared to carry out a demonstration in the Illinois Basin. A database of the proposed study area and the web-based system to facilitate geologic and seismic data input are ready for this demonstration as are mapping tools for comparison and observations.

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NMR CHARACTERIZATIONS OF PROPERTIES OF HETEROGENEOUS MEDIA

A critical and long-standing need within the petroleum industry is the specification of suitable petrophysical properties for mathematical simulation of fluid flow in petroleum reservoirs (i.e., reservoir characterization). The development of accurate reservoir characterizations is extremely challenging. Property variations may be described on many scales, and the information available from measurements reflect different scales. In fact, experiments on laboratory core samples, well-log data, well-test data, and reservoir-production data all represent information potentially valuable to reservoir characterization, yet they all reflect information about spatial variations of properties at different scales. Nuclear magnetic resonance (NMR) spectroscopy and imaging (MRI) provide enormous potential for developing new descriptions and understandings of heterogeneous media. NMR has the rare capability to probe permeable media non-invasively, with spatial resolution, and it provides unique information about molecular motions and interactions that are sensitive to morphology. NMR well-logging provides the best opportunity ever to resolve permeability distributions within petroleum reservoirs. We develop MRI methods to determine, for the first time, spatially resolved distributions of porosity and permeability within permeable media samples that approach the intrinsic scale: the finest resolution of these macroscopic properties possible. To our knowledge, this is the first time that the permeability is actually resolved at a scale smaller than the sample. In order to do this, we have developed a robust method to determine of relaxation distributions from NMR experiments and a novel implementation and analysis of MRI experiments to determine the amount of fluid corresponding to imaging regions, which are in turn used to determine porosity and saturation distributions. We have developed a novel MRI experiment to determine velocity distributions within flowing experiments, and developed methodology using that data to determine spatially resolved permeability distributions. We investigate the use of intrinsic properties for developing improved correlations for predicting permeability from NMR well-logging data and for obtaining more accurate estimates of multiphase flow properties--the relative permeability and capillary pressure--from displacement experiments. We demonstrate the use of MRI measurements of saturation and relaxation for prediction wetting-phase relative permeability for unstable experiments. Finally, we developed an improved method for determining surface relaxivity with NMR experiments, which can provide better descriptions of permeable media microstructures and improved correlations for permeability predictions.

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INEXPENSIVE CO{sub 2} THICKENING AGENTS FOR IMPROVED MOBILITY CONTROL OF CO{sub 2} FLOODS

The objective of this research was the design, synthesis and evaluation of inexpensive, nonfluorous carbon dioxide thickening agents. We followed the same strategy employed in the design of fluorinated CO{sub 2} polymeric thickeners. First, a highly CO{sub 2}-philic, hydrocarbon-based monomer was to be identified. Polymers or oligomers of this monomer were then synthesized. The second step was to be completed only when a CO{sub 2}-soluble polymer that was soluble in CO{sub 2} at pressures comparable to the MMP was identified. In the second step, viscosity-enhancing associating groups were to be incorporated into the polymer to make it a viable thickener that exhibited high CO{sub 2} solubility at EOR MMP conditions. This final report documents the CO{sub 2} solubility of a series of commercial and novel polymers composed of carbon, hydrogen, oxygen and, in some cases, nitrogen.

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An Assessment of Geological Carbon Sequestration Options in the Illinois Basin

The Midwest Geological Sequestration Consortium (MGSC) has investigated the options for geological carbon dioxide (CO{sub 2}) sequestration in the 155,400-km{sup 2} (60,000-mi{sup 2}) Illinois Basin. Within the Basin, underlying most of Illinois, western Indiana, and western Kentucky, are relatively deeper and/or thinner coal resources, numerous mature oil fields, and deep salt-water-bearing reservoirs that are potentially capable of storing CO{sub 2}. The objective of this Assessment was to determine the technical and economic feasibility of using these geological sinks for long-term storage to avoid atmospheric release of CO{sub 2} from fossil fuel combustion and thereby avoid the potential for adverse climate change. The MGSC is a consortium of the geological surveys of Illinois, Indiana, and Kentucky joined by six private corporations, five professional business associations, one interstate compact, two university researchers, two Illinois state agencies, and two consultants. The purpose of the Consortium is to assess carbon capture, transportation, and storage processes and their costs and viability in the three-state Illinois Basin region. The Illinois State Geological Survey serves as Lead Technical Contractor for the Consortium. The Illinois Basin region has annual emissions from stationary anthropogenic sources exceeding 276 million metric tonnes (304 million tons) of CO{sub 2} (&gt;70 million tonnes (77 million tons) carbon equivalent), primarily from coal-fired electric generation facilities, some of which burn almost 4.5 million tonnes (5 million tons) of coal per year. Assessing the options for capture, transportation, and storage of the CO{sub 2} emissions within the region has been a 12-task, 2-year process that has assessed 3,600 million tonnes (3,968 million tons) of storage capacity in coal seams, 140 to 440 million tonnes (154 to 485 million tons) of capacity in mature oil reservoirs, 7,800 million tonnes (8,598 million tons) of capacity in saline reservoirs deep beneath geological structures, and 30,000 to 35,000 million tonnes (33,069 to 38,580 million tons) of capacity in saline reservoirs on a regional dip &gt;1,219 m (4,000 ft) deep. The major part of this effort assessed each of the three geological sinks: coals, oil reservoirs, and saline reservoirs. We linked and integrated options for capture, transportation, and geological storage with the environmental and regulatory framework to define sequestration scenarios and potential outcomes for the region. Extensive use of Geographic Information Systems (GIS) and visualization technology was made to convey results to project sponsors, other researchers, the business community, and the general public. An action plan for possible technology validation field tests involving CO{sub 2} injection was included in a Phase II proposal (successfully funded) to the U.S. Department of Energy with cost sharing from Illinois Clean Coal Institute.

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INTEGRATING P-WAVE AND S-WAVE SEISMIC DATA TO IMPROVE CHARACTERIZATION OF OIL RESERVOIRS

The data used in this study were acquired by nine-component (9C) vertical seismic profile (VSP), using three orthogonal vector sources. The 9C vertical seismic profile is capable of generating P-wave mode and the fundamental S-wave mode (SH-SH and SV-SV) directly at the source station and permits the basic components of elastic wavefield (P, SH-SH and SV-SV) to be separated from one another for the purposes of imaging. Analysis and interpretations of data from the study area show that incident full-elastic seismic wavefield is capable of reflecting four different wave modes, P, SH , SV and C which can be utilized to fully understand the architecture and heterogeneities of geologic sequences. The conventional seismic stratigraphy utilizes only reflected P-wave modes. The notation SH mode is the same as SH-SH; SV mode means SV-SV and C mode which is a converted shear wave is a special SV mode and is the same as P-SV. These four wave modes image unique geologic stratigraphy and facies and at the same time reflect independent stratal surfaces because of the unique orientation of their particle-displacement vectors. As a result of the distinct orientation of individual mode.s particle-displacement vector, one mode may react to a critical subsurface sequence more than the other. It was also observed that P-wave and S-wave do not always reflect from the same stratal boundaries. At inline coordinate 2100 and crossline coordinates of 10,380, 10430, 10480 and 10,520 the P-wave stratigraphy shows coherency at time slice 796 m/s and C-wave stratigraphy shows coherency at time slice 1964 m/s at the same inline coordinate and crossline coordinates of 10,400 to 10470. At inline coordinate 2800 and crossline coordinate 10,650, P-wave stratigraphy shows coherency at time slice 792 m/s and C-wave stratigraphy shows coherency at time slice 1968 m/s. The utilization of full-elastic seismic wavefield needs to be maximized in oil and gas explorations in order to optimize the search for hydrocarbons.

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DEVELOPMENT AND MANUFACTURE OF COST EFFECTIVE COMPOSITE DRILL PIPE

This technical report presents the engineering research, process development and data accomplishments that have transpired to date in support of the development of Cost Effective Composite Drill Pipe (CDP). The report presents progress made from October 1, 2003 through September 30, 2004 and contains the following discussions: (1) Direct Electrical Connection for Rotary Shoulder Tool Joints; (2) Conductors for inclusion in the pipe wall (ER/DW-CDP,4051 ); (3) Qualify fibers from Zoltek; (4) Qualify resin from Bakelite; (5) First commercial order for SR-CDP from Integrated Directional Resources (SR-CDP,4051 ); and (6) Preparation of papers for publication and conference presentations.

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SEISMIC DETERMINATION OF RESERVOIR HETEROGENEITY: APPLICATION TO THE CHARACTERIZATION OF HEAVY OIL RESERVOIRS

The objective of the project was to examine how seismic and geologic data can be used to improve characterization of small-scale heterogeneity and their parameterization in reservoir models. The study focused on West Coalinga Field in California. The project initially attempted to build reservoir models based on different geologic and geophysical data independently using different tools, then to compare the results, and ultimately to integrate them all. We learned, however, that this strategy was impractical. The different data and tools need to be integrated from the beginning because they are all interrelated. This report describes a new approach to geostatistical modeling and presents an integration of geology and geophysics to explain the formation of the complex Coalinga reservoir.

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MAPPING OF RESERVOIR PROPERTIES AND FACIES THROUGH INTEGRATION OF STATIC AND DYNAMIC DATA

Knowledge of the distribution of permeability and porosity in a reservoir is necessary for the prediction of future oil production, estimation of the location of bypassed oil, and optimization of reservoir management. The volume of data that can potentially provide information on reservoir architecture and fluid distributions has increased enormously in the past decade. The techniques developed in this research will make it easier to use all the available data in an integrated fashion. While it is relatively easy to generate plausible reservoir models that honor static data such as core, log, and seismic data, it is far more difficult to generate plausible reservoir models that honor dynamic data such as transient pressures, saturations, and flow rates. As a result, the uncertainty in reservoir properties is higher than it could be and reservoir management can not be optimized. In this project, we have developed computationally efficient automatic history matching techniques for generating geologically plausible reservoir models which honor both static and dynamic data. Specifically, we have developed methods for adjusting porosity and permeability fields to match both production and time-lapse seismic data and have also developed a procedure to adjust the locations of boundaries between facies to match production data. In all cases, the history matched rock property fields are consistent with a prior model based on static data and geologic information. Our work also indicates that it is possible to adjust relative permeability curves when history matching production data.

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FIELD DEMONSTRATION OF CARBON DIOXIDE MISCIBLE FLOODING IN THE LANSING-KANSAS CITY FORMATION, CENTRAL KANSAS

A pilot carbon dioxide miscible flood was initiated in the Lansing Kansas City C formation in the Hall Gurney Field, Russell County, Kansas. Continuous carbon dioxide injection began on December 2, 2003. By the end of June 2004, 6.26 MM lb of carbon dioxide were injected into the pilot area. Carbon dioxide injection rates averaged about 250 MCFD. Carbon dioxide was detected in one production well near the end of May. The amount of carbon dioxide produced was small during this period. Wells in the pilot area produced 100% water at the beginning of the flood. Oil production began in February, increasing to an average of about 2.5 B/D in May and June. Operational problems encountered during the initial stages of the flood were identified and resolved.

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TIME-LAPSE MODELING AND INVERSION OF CO2 SATURATION FOR SEQUESTRATION AND ENHANCED OIL RECOVERY

In the fifth quarter of this DOE NETL project, they have implemented an algorithm that inverts for changes in fluid properties over time using time-lapse seismic anomalies. This algorithm constitutes the second step in the inversion procedure for Phase III of the project. They demonstrate this inversion procedure with a synthetic data example. Additional activities in this reporting period include a trip by the Principal investigator to an International Monitoring Workshop sponsored by the IEA Greenhouse Gas R and D Program in Santa Cruz, California. In the next quarter, they will further process the Sleipner data to prepare it for later inversion, and continue investigating alternative methods for calculating properties of oil/brine/CO{sub 2} systems.

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INTEGRATED APPROACH FOR THE PETROPHYSICAL INTERPRETATION OF POST-AND PRE-STACK 3-D SEISMIC DATA, WELL-LOG DATA, CORE DATA, GEOLOGICAL INFORMATION AND RESERVOIR PRODUCTION DATA VIA BAYESIAN STOCHASTIC INVERSION

The present report summarizes the work carried out between September 30, 2000 and September 30, 2004 under DOE research contract No. DE-FC26-00BC15305. During the three-year project period, we carried out extensive studies on the inversion post-stack and pre-stack data together with well logs, petrophysical information and fluid flow data. We have achieved all the project goals including development of algorithm for joint inversion of pre-stack seismic data, well logs, and time records of fluid production measurements using stochastic inversion algorithms which were demonstrated on realistic synthetic and field data. Our accomplishments are: (1) Joint inversion of post-stack seismic, well log, fluid flow, and petrophysical data: we demonstrated the technique with application to data from the Gulf of Mexico. (2) Development of a robust pre-stack full waveform inversion algorithm: A new approach based on iteration-adaptive regularization that makes use of plane wave transformed seismic data, was developed and applied to OBC dataset from the Gulf of Thailand. The algorithm was also implemented on a cluster of personal computers. (3) Joint inversion of pre-stack seismic and well-log data: A new stochastic optimization algorithm that makes use of the essential features of seismic and well log data was developed and tested on realistic synthetic dataset. (4) Joint inversion of pre-stack seismic and fluid flow data: A novel technique was developed to optimally combine seismic and flow data. The technique makes very realistic estimate of porosity; sensitivity of the flow parameters to two disparate datasets was studied extensively. (5) Direct estimation of petrophysical parameters from seismic data: The pre-stack waveform inversion was modified to invert directly for porosity and saturation using the Biot-Gassmann equation at each iteration step. The final report contains abridged versions of some of our inventions. The works resulted in several peer-reviewed publications. Five papers have been communicated for peer-reviewed publication, and seven papers were presented at conferences. All of these publications and presentations stemmed from work directly related to the goals of our DOE project.

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ADVANCED HOT GAS FILTER DEVELOPMENT

Iron aluminide hot gas filters have been developed using powder metallurgy techniques to form seamless cylinders. Three alloys were short-term corrosion tested in simulated IGCC atmospheres with temperatures between 925 F and 1200 F with hydrogen sulfide concentrations ranging from 783 ppm{sub v} to 78,300 ppm{sub v}. Long-term testing was conducted for 1500 hours at 925 F with 78,300 ppm{sub v}. The FAS and FAL alloys were found to be corrosion resistant in the simulated environments. The FAS alloy has been commercialized.

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TIME-LAPSE MODELING AND INVERSION OF CO2 SATURATION FOR SEQUESTRATION AND ENHANCED OIL RECOVERY

In the fourth quarter of this DOE NETL project, they have developed an algorithm for generating time-lapse seismic anomalies from changes in fluid properties over time. This forward-modeling algorithm constitutes the first step in the inversion procedure of Phase III of the project. Examples were generated illustrating the flexibility of this approach. Additional activities in this reporting period included a trip by the Principal Investigator to the 7th International Conference on Greenhouse Gas Control Technologies (GHGT-7) in Vancouver, Canada, September 5-9, 2004. In the next quarter, they will work on the second step of the inversion procedure, namely, the inversion of the seismic time-lapse anomalies to obtain changes in fluid properties, and will continue investigating alternative methods for calculating properties of oil/brine/CO{sub 2} and brine/CO{sub 2} systems.

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IMPROVED MISCIBLE NITROGEN FLOOD PERFORMANCE UTILIZING ADVANCED RESERVOIR CHARACTERIZATION AND HORIZONTAL LATERALS IN A CLASS I RESERVOIR--EAST BINGER (MARCHAND) UNIT

A significant work program has been implemented in the East Binger Unit (''EBU'') miscible nitrogen injection project in an effort to reduce gas cycling and economically increase ultimate oil recovery. This work includes the drilling of new wells, both horizontal and vertical, as well as pattern realignment through producer-to-injector conversions. Monitoring of overall performance of the pilot area continues. Response to the various projects continues to be very favorable. Injection into the pilot area has nearly doubled, while gas production and nitrogen content of produced gas have both decreased. Nitrogen recycle within the pilot area has increased to 23% in recent months, but this is still far below the 58% recycle prior to initiation of the project. Two additional wells--EBU 65-2 and EBU 67-2--were brought on line during this reporting period. EBU 65-2 was successfully sidetracked after encountering thin pay on the edge of the reservoir, and is awaiting conversion to nitrogen injection service. The early performance of EBU 67-2 has been as predicted.

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LOTT RANCH 3D PROJECT

The Lott Ranch 3D seismic prospect located in Garza County, Texas is a project initiated in September of 1991 by the J.M. Huber Corp., a petroleum exploration and production company. By today's standards the 126 square mile project does not seem monumental, however at the time it was conceived it was the most intensive land 3D project ever attempted. Acquisition began in September of 1991 utilizing GEO-SEISMIC, INC., a seismic data contractor. The field parameters were selected by J.M. Huber, and were of a radical design. The recording instruments used were GeoCor IV amplifiers designed by Geosystems Inc., which record the data in signed bit format. It would not have been practical, if not impossible, to have processed the entire raw volume with the tools available at that time. The end result was a dataset that was thought to have little utility due to difficulties in processing the field data. In 1997, Yates Energy Corp. located in Roswell, New Mexico, formed a partnership to further develop the project. Through discussions and meetings with Pinnacle Seismic, it was determined that the original Lott Ranch 3D volume could be vastly improved upon reprocessing. Pinnacle Seismic had shown the viability of improving field-summed signed bit data on smaller 2D and 3D projects. Yates contracted Pinnacle Seismic Ltd. to perform the reprocessing. This project was initiated with high resolution being a priority. Much of the potential resolution was lost through the initial summing of the field data. Modern computers that are now being utilized have tremendous speed and storage capacities that were cost prohibitive when this data was initially processed. Software updates and capabilities offer a variety of quality control and statics resolution, which are pertinent to the Lott Ranch project. The reprocessing effort was very successful. The resulting processed data-set was then interpreted using modern PC-based interpretation and mapping software. Production data, log data, and scout ticket data were integrated with the 3D interpretations to evaluate drilling opportunities resulting in an initial three well drilling program. Thousands of miles of signed bit data exist. Much of this data was processed during a time when software and hardware capabilities were either incapable or cost prohibitive to glean the full potential of the data. In fact in some circles signed bit gained an undeserved reputation for being less than optimum. As a consequence much of the older signed bit data sits on the shelf long forgotten or overlooked. With the high cost of new acquisition and permitting it might behoove other exploration companies to reconsider resurrecting perfectly viable existing volumes and have them reprocessed at a fraction of the cost of new acquisition.

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