AndreaBozzo/ceres-open-data-index huggingface dataset:
PRELIMINARY RESULTS OF ORGANIC MATURATION, TEMPERATURE, AND PRESSURE STUDIES IN THE PACIFIC CREEK AREA, SUBLETTE COUNTY, WYOMING

Preliminary investigations of a sequence of Upper Cretaceous and Lower Tertiary rocks in the Pacific Creek area of the northeastern Green River Basin show that studies of organic maturation, subsurface temperature, and formation pressure may help define prospective gas-saturated intervals and delineate areas of maximum gas resource potential. At about 11,600 ft (3,500 m), near the base of the Upper Cretaceous Lance Formation, the top of significantly high overpressure has been identified. Drillstem test data indicate that the pressure gradient is as high as 0.84 psi/ft (19.0 KPa/m). The development of overpressure may involve several processes; however, interpretation of the available information indicates that the active generation of large amounts of wet gas is one of the more important processes. A vertical profile of organic maturation, determined by vitrinite reflectance and color alteration of organic material, shows that the top of overpressure and beginning phase of wet-gas generation occurs within, but well below the top of, the "oil window." The present minimum temperature at . 0 0 the top of overpressure is at least 190 F (88 C). This temperature was determined from uncorrected bottom-hole temperatures recorded during logging of wells drilled in the area. The preservation of abnormally high pressures is probably due to presently active generation of gas in a thick interval of discontinuous, very low-permeability shales, siltstones, and sandstones.

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APPLICATION OF ADVANCED RESERVOIR CHARACTERIZATION, SIMULATION AND PRODUCTION OPTIMIZATION STRATEGIES TO MAXIMIZE RECOVERY IN SLOPE AND BASIN CLASTIC RESERVOIRS, WEST TEXAS (DELAWARE BASIN)

The objective of this Class III project is to demonstrate that detailed reservoir characterization of clastic reservoirs in basinal sandstones of the Delaware Mountain Group in the Delaware Basin of West Texas and New Mexico is a cost-effective way to recover more of the original oil in place by strategic infill-well placement and geologically based field development. The study focused on Geraldine Ford field, which produces from the upper Bell Canyon Formation (Ramsey sandstone), and West Ford field, which produces from the upper Cherry Canyon and lower Bell Canyon Formations. Reservoirs in these and other Delaware Mountain Group fields have low producibility (average recovery 44 percent of the original oil in place) because of a high degree of vertical and lateral heterogeneity caused by depositional processes and post depositional diagenetic modification. Outcrop analogs were studied to better interpret the depositional processes that formed the reservoirs at Geraldine Ford and West Ford fields and to determine the dimensions of reservoir sandstone bodies. Strata relationships examined in laterally continuous outcrop exposures of upper Bell Canyon sandstones in Culberson County, Texas, indicate that the sandstones were deposited by high- and low-density turbidity currents in a basinal deep-water setting. The fundamental depositional element is the channel with attached levees and lobes. These elements appear to initially step into the basin, aggrade, then step back toward the shelf.

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Nonconventional Natural Gas Resources Sub-Task IV: Gas in Tight Formations to the Federal Power Commission

Significantly large nonconventional resources of natural gas are either known or inferred to occur in many regions of the United Stares; - these resources are characterized by very low permeability to gas flow so that present production techniques are inadequate to develop such resources a s economically recoverable reserves. In general, the low flow rate for gas. leads directly to high wellhead costs, at least several fold greater than current wellhead prices for conventionally produced natural gas. Thus, these resources, whether identified or undiscovered, fall  in the category of subeconomic or noncommercial.

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Attrition Resistant Iron-Based Fischer-Tropsch Catalysts

The Fischer-Tropsch (F-T) reaction provides a way of converting coal-derived synthesis gas (CO H2) to liquid fuels. Since the reaction is highly exothermic, one of the major problems in control of the reaction is heat removal. Recent work has shown that the use of slurry bubble column reactors (SBCRs) can largely solve this problem. Iron-based (Fe) catalysts are preferred catalysts for F-T when using low CO/H2 ratio synthesis gases derived from modern coal gasifiers. This is because in addition to reasonable F-T activity, the F-T catalysts also possess high water gas shift (WGS) activity. However, a serious problem with the use of Fe catalysts in a SBCR is their tendency to undergo attrition. This can cause fouling/plugging of downstream filters and equipment, making the separation of catalyst from the oil/wax product very difficult if not impossible, and results in a steady loss of catalyst from the reactor. The objectives of this research are to develop a better understanding of the parameters affecting attrition resistance of Fe F-T catalysts suitable for use in SBCRs and to incorporate this understanding into the design of novel Fe catalysts having superior attrition resistance. Catalyst preparations will be based on the use of spray drying and will be scalable using commercially available equipment. The research will employ among other measurements, attrition testing and F-T synthesis, including long duration slurry reactor runs in order to ascertain the degree of success of the various preparations. The goal is to develop an Fe catalyst which can be used in a SBCR having only an internal filter for separation of the catalyst from the liquid product, without sacrificing F-T activity and selectivity. Two doubly promoted iron catalysts of standard Ruhrchemie composition were prepared by coprecipitation followed by spray drying (atomization). These catalysts had a particle size of 20 to 40 ?m. One catalyst had no silica (HPR-23) while the other had a significant amount of silica (HPR-22). The catalyst with no silica (HPR-23) had much higher activity and selectivity. It gave 95% CO conversion at 1.48 MPa, H2/CO=0.67, and 2 nL/(g of cat-h). Also, the selectivity to C2   hydrocarbon was 95% and the " was around 0.9. The attrition resistance of HPR-23 was also significantly better than HPR-22. It appears that silica is detrimental to performance of a spray dried iron catalyst.

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C02 HUFF-N-PUFF PROCESS IN A LIGHT OIL SHALLOW SHELL CARBONATE RESERVOIR

The application of cyclic CO2, often referred to as the CO2 Huff-n-Puff process, may find its niche in the maturing waterfloods of the Permian Basin. Coupling the CO2 H-n-P process to miscible flooding applications could provide the needed revenue to sufficiently mitigate near-term negative cash flow concerns in the capital intensive miscible projects. Texaco Exploration & Production Inc. and the U. S. Department of Energy have teamed up in an attempt to develop the CO2 Huff-n-Puff process in the Grayburg and San Andres formations; a light oil, shallow shelf carbonate reservoir that exists throughout the Permian Basin. This cost-shared effort is intended to demonstrate the viability of this underutilized technology in a specific class of domestic reservoir.

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ADVANCED OIL RECOVERY TECHNOLOGIES FOR IMPROVED RECOVERY FROM SLOPE BASIN CLASTIC RESERVOIRS, NASH DRAW BRUSHY CANYON POOL, EDDY COUNTY, NM

The overall objective of this project is to demonstrate that a development program based on advanced reservoir management methods can significantly improve recovery. The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared existing technology applications and (2) to transfer these advanced methodologies to oil producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry.

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ADVANCED OIL RECOVERY TECHNOLOGIES FOR IMPROVED RECOVERY FROM SLOPE BASIN CLASTIC RESERVOIRS, NASH DRAW BRUSH CANYON POOL, EDD COUNTY, NEW MEXICO

The basic driver for this project is the low recovery observed in Delaware reservoirs, such as the Nash Draw Pool (NDP). This low recovery is caused by low reservoir energy, less than optimum permeability's and porosities, and inadequate reservoir characterization and reservoir management strategies which are typical of projects operated by independent producers. Rapid oil decline rates and high gas/oil ratios are typically observed in the first year of primary production. Based on the production characteristics that have been observed in similar Delaware fields, pressure maintenance is a likely requirement at the Nash Pool. Three basic constraints to producing the Nash Draw Brushy Canyon Reservoir are: (1) limited areal and interwell geologic knowledge, (2) lack of an engineering tool to evaluate the various producing strategies, and (3) limited surface access prohibiting development with conventional drilling. The limited surface access is caused by the proximity of underground potash mining and surface playa lakes.

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Application of Reservoir Characterization and Advanced Technology to Improve Recovery and Economics in a Lower Quality Shallow Shelf Carbonate  Reservoir

The Oxy West Welch project is designed to demonstrate how the use of advanced technology can improve the economics of miscible CO, injection projects in a lower quality shallow shelf carbonate reservoir. The research and design phase primarily involves advanced reservoir characterization and accelerating the production response. The demonstration phase will implement the reservoir management plan based on an optimum miscible CO, flood as designed in the initial phase. During Budget Period 1, work was completed on the CO, stimulation treatments and the hydraulic fracture design. Analysis of the CO, stimulation treatment provided a methodology for predicting results. The hydraulic fracture treatment proved up both the fracture design approach and the use of passive seismic for mapping the fracture wing orientation. Although the 3-D seismic interpretation is still being integrated into the geologic model and interpretation of borehole seismic is still underway, the simulator has been enhanced to the point of giving good waterflood history matches. The simulator forecasted results for an optimal designed miscible CO, flood in the demonstration area gave sufficient economics to justify continuation of the project into Budget Period 2.

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Application Of Reservoir Characterization And Advanced Technology To Improve Recovery And Economics In A Lower Quality Shallow Shelf Carbonate Reservoir

The Oxy West Welch project is designed to demonstrate how the use of advanced technology can improve the economics of miscible CO2 injection projects in a lower quality shallow shelf carbonate reservoir. The research and design phase primarily involves advanced reservoir characterization and accelerating the production response. The demonstration phase will implement the reservoir management plan based on an optimum miscible CO2 flood as designed in the initial phase.

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Valley-Fill Sandstones in the Kootenai Formation on the Crow Indian Reservation, South-Central Montana

Subsurface data is being collected, organized, and a digital database is being prepared for the project. An ACCESS database and PC-Arcview will be used to manage and interpret the data. All of the four 30? X 60? geologic quadrangles have been scanned to produce a digital surface geologic data base for the C ow Reservation and all are nearing completion. Writing of the map explanations has begun.

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Management and Operating Contract for the DOE's National Oil and Related Programs

As the management and operating contractor for the US DOE's National Oil and Related Programs, BDM-Oklahoma has responsibility for performing high quality research and maintaining technological excellence, while managing the programs and the National Institute for Petroleum and Energy Research facility in a safe and environmentally compliant manner. Responsibilities fall within compliance, upstream petroleum technology, processing and utilization, and petroleum program integration categories. Accomplishments are reported for the fiscal year 1997.

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Application Of Reservoir Characterization And Advanced Technology To Improve Recovery And Economics In A Lower Quality Shallow Shelf San Andres Reservoir

The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (lOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of lOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization.

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Assistance to the State Underground Injection Control Programs and Oil and Gas Industry Through Continuation of Risk Based Data Management  System Implementation and Technology Transfer and Area of Review Workshops

To provide additional assistance to state Oil and Gas agencies and producers in developing formalized environmental risk management practices and to assist both Direct Implementation and Primary state class II UIC Directors in establishing workable AOR variance programs and to assist operators of both small and large O&G producing companies with Class II injection well AOR requirements

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The Utilization of the Microflora Indigenous to and Present in Oil-Bearing Formations to Selectively Plug the More Porous Zones Thereby Increasing Oil Recovery During Waterflooding

This project is a field demonstration of the ability of in-situ indigenous microorganisms in the North Blowhorn Creek Oil Field to reduce the flow of injection water in the more permeable zones thereby diverting flow to other areas of the reservoir and thus increase the efficiency of the waterflooding operation. This effect is to be accomplished by adding inorganic nutrients in the form of potassium nitrate and orthophosphate, to the injection water. Work on the project is divided into three phases, Planning and Analysis (9 months), Implementation (45 months), and Technology Transfer (12 months). In Phase I, which has been completed, the following results were obtained. Two new wells were drilled in the field and live cores were recovered. Analyses of the cores proved that viable microorganisms were present and since no sulfate-reducing bacteria (SRB) were found, the area in which the wells were drilled, probably had not been impacted by injection water, since SRB were prevalent in fluids from most wells in the field. Laboratory waterflooding tests using live cores demonstrated that the rate of flow of simulated production water through the core increased with time when used alone while the rate of flow decreased when nitrate and phosphate salts were added to the simulated production water. Since there is only a small amount of pressure on the influent, the simulated production water was not forced to sweep other areas of the core (as would be expected in the reservoir since the water is injected under pressure). The field demonstration (Phase II) involves adding nutrients to four injector wells and monitoring the surrounding producers. The exact kind and amounts of nutrients to be employed and the schedule for their injection were formulated on the basis of the information obtained in the laboratory waterflooding tests conducted using the live cores from the field. Results obtained in these tests will not only be compared to historical data for the wells but also to four injectors and their corresponding producers (control) which were chosen for their similarity to the four test patterns. A preliminary geological and petrophysical characterization of the reservoir has been made and baseline chemical and microbiological data obtained on all of the test and control wells in the first test pattern (two injector wells and nine producing wells). Injection of nutrients began in the first test well on November 21, 1994.

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ECONOMIC RECOVERY OF OIL TRAPPED AT FAN MARGINS USING HIGH ANGLE WELLS AND MULTIPLE HYDRAULIC FRACTURES

The distal fan margin in the northeast portion of the Yowlumne field contains significant reserves but is not economic to develop using vertical wells. Numerous interbedded shales and deteriorating rock properties limit producibility. In addition, extreme depths (13,000 ft) present a challenging environment for hydraulic fracturing and artificial lift. Lastly, a mature waterflood increases risk because of the uncertainty with size and location of flood fronts. This project attempts to demonstrate the effectiveness of exploiting the distal fan margin of this slope-basin clastic reservoir through the use of a high-angle well completed with multiple hydraulic-fracture treatments. The combination of a high-angle (or horizontal) well and hydraulic fracturing will allow greater pay exposure than can be achieved with conventional vertical wells while maintaining vertical communication between thin interbedded layers and the wellbore. The equivalent production rate and reserves of three vertical wells are anticipated at one-half to two-thirds the cost.

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INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

The objective of this project is to increase heavy oil reserves in a portion of the Wilmington oil Field, near Long Beach, California, by implementing advanced reservoir characterization and thermal production technologies. Based on the knowledge and experience gained with this project, these technologies are intended to be extended to other sections of the Wilmington Oil Field, and, through technology transfer, will be available to increase heavy oil reserves in other slope and basin clastic (SBC) reservoirs. The project involves implementing thermal recovery in the southern half of the Fault Block II-A Tar zone. The existing steamflood in Fault Block II-A has been relatively inefficient due to several producibility problems which are common in SBC reservoirs.  inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil, and nonuniform distribution of remaining oil have all contributed to poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated formation sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. A suite of advanced reservoir characterization and thermal production technologies are being applied during the project to improve oil recovery efficiency and reduce operating costs, including: 1. Developing three-dimensional (3-D) deterministic and stochastic geologic and reservoir simulation models. 2. Developing computerized 3-D visualizations of the geologic and reservoir simulation models to aid in analysis. 3. Performing detailed studies of the geochemical interactions between the injected steam and the formation rock and fluids. 4. Performing pilot tests of steam injection and production via new horizontal wells. 5. Performing pilot tests of hot water alternating steam (WAS) drive in the existing steam drive area to improve thermal efficiency. 6. Installing a 2100-ft insulated, subsurface harbor channel crossing to supply steam to an island location. 7. Testing a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. 8. Applying advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring and evaluation.

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ECONOMIC RECOVERY OF OIL TRAPPED AT FAN MARGINS USING HIGH ANGLE WELLS AND MULTIPLE HYDRAULIC FRACTURES

The distal fan margin in the northeast portion of the Yowlumne field contains significant reserves but is not economic to develop using vertical wells. Numerous interbedded shales and deteriorating rock properties limit producibility. In addition, extreme depths (13,000 ft) present a challenging environment for hydraulic fracturing and artificial lift. Lastly, a mature waterflood increases risk because of the uncertainty with size and location of flood fronts. This project attempts to demonstrate the effectiveness of exploiting the distal fan margin of this slope-basin clastic reservoir through the use of a high-angle well completed with multiple hydraulic-fracture treatments. The combination of a high-angle (or horizontal) well and hydraulic fracturing will allow greater pay exposure than can be achieved with conventional vertical wells while maintaining vertical communication between thin interbedded layers and the wellbore. The equivalent production rate and reserves of three vertical wells are anticipated at one-half to two-thirds the cost. An analogous well was hydraulically fractured to obtain fracture-treatment design parameters for the proposed high-angle well. This well was the first frac in the northwest fan margin, and it treated with a higher frac gradient (1.06 psilft) than the 0.91 psilft gradient observed in the northeast fan margin (where the high-angle well is proposed to be drilled). Microseismic events were passively monitored during the frac from an offset well to determine fracture geometry and azimuth. A NW -SE azimuth was detected, compared to the expected NNE-SSW azimuth. Knowledge of fracture azimuth was useful for determining location and azimuth of the high-angle well. The reservoir geology of the northeast fan margin was re-evaluated. Petrophysical properties were derived from core, log, and RFT data. In general, only slight  modifications of previous interpretations were necessary. As expected, rock properties were shown to deteriorate in a easterly direction, towards the distal margin. The five major flow ,units were subdivided into ten layers. Rock properties were calculated and mapped for each layer. The detailed reservoir geology was then inserted in a fine-grid, partial-field reservoir simulation model. The model was history matched, with some layers appearing to be more swept than expected. Upon completion of history matching, the model was used to test a variety of development alternatives aimed at optimizing project economics. Model forecasts compared slant well performance to more conventional development options and quantified rate impacts from changes in well location, orientation, and completion technique. An east-to west slant well with multiple hydraulic fractures proved to be the optimal alternative to develop the fan-margin region. Model results indicated the well could initially produce 2180 BOPD and recover 724 MBO of reserves (net of  interference).

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