AndreaBozzo/ceres-open-data-index huggingface dataset:
Applications Of Advanced Petroleum Production Technology And Water Alternating Gas Injection For Enhanced Oil Recovery - Mattoon Oil Field, Illinois

Phase I results of a CO2-assisted oil recovery demonstration project in selected Cypress Sandstone reservoirs at Mattoon Field, Illinois are reported. The design and scope of this project included CO2 injectivity testing in the Pinnell and Sawyer units, well stimulation treatments with CO, in the Strung unit, and infill well drilling, completion and oil production. The field activities were supported by extensive C0,oil-water coreflood experiments, CO, oil phase internion experiments, and integrated geologic modeling and reservoir simulations. The progress of the project was made public through presentations at an industry meeting and a DOE'S contractors'symposium, through quarterly reports and one-to-one consultations with interested operators. Phase II of this project was not implemented. It would have been a water-alternating-gas (WAG) project of longer duration.

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Green River Formation Water Flood Demonstration Project

The successful water flood of the Green River Formation in the Monument Butte unit was analyzed in detail in the last yearly report. It was shown that primary recovery and the water flood in the unit were typical of oil production from an undersaturated oil reservoir close to its bubble point. The reservoir performance of the smaller Travis unit was also analyzed. The Monument Butte unit is currently producing at around 300 barrels per day of oil. Two of the new wells drilled in the unit had zones pressurized by the water flood. The third well produced from pressurized as well as from zones which were unaffected by the water flood. The water flood response of the Travis unit is slow possibly due to problems of reservoir continuity. Water  injection continues in the unit and the reservoir pressure is increasing steadily. The new well that was drilled in Travis, did not intersect the Lower Douglas Creek Sand into which most of the water has been injected. Plans for water flooding the Boundary unit were drawn.

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ASSIST IN THE RECOVERY OF BYPASSED OIL FROM RESERVOIRS IN THE GULF OF MEXICO

The objective of this research is to assist in the recovery of no contacted oil from known reservoirs on the Outer Continental Shelf in the Gulf of Mexico. Mature offshore reservoirs, declining oil reserves, declining production, and other natural forces currently are accelerating the abandonment of off shore oil resources and production platforms. As these offshore wells are plugged and the platforms are abandoned, an enormous volume of remaining oil is permanently abandoned.  Significant quantities of this oil could be recovered using advanced technologies now available if the resource can be identified.

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

Field investigation of the Kootenai valley-fill sandstones was begun in the first quarter.  About one half of the outcrop belt was inventoried for occurrences of channel sandstone before heavy snows came into the area.  Five exposures of valley-fill sandstone have been located, of these two are 15 meters (50 feet) or greater in thickness and have excellent porosity and permeability.

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Applications of Advanced Petroleum Production Technology and Water Alternating Gas Injection for Enhanced Oil Recovery - Mattoon Oil Field, Illinois

Phase I results of a CO2-assisted or recovery demonstration project in selected Cypress Sandstone reservoirs at Mattoon Reid, Illinois are reported. The design and scope of this project included CO2 injectivity testing in the Pinnell and Sawyer units, well stimulation treatments with CO2 in the Strong unit, and infill well drilling, completion and oil production. The field activities were supported by extensive CO2-oil-water coreflood experiments, CO2-oH phase interaction experiments, and integrated geologic modeling and reservoir simulations. The progress of the project was made public through presentations at an industry meeting and a DOE's con1ractors'symposium, through quarterly reports and one-to-one consultations with interested operators. Phase II of this project was not implemented. It would have been a water-alternating-gas (YVAG) project of longer duration.

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FACIES DEVELOPMENT OF THE GALLUP FORMATION

Recent oil and gas discoveries in sandstone lenses of the Gallup formation or its stratigraphic equivalent in the San Juan Basin have stimulated subsurface exploration in a search for similar stratigraphic traps.  The purpose of this article is to discuss briefly the Gallup formation of upper Cretaceous age and its gradation from a porous massive sandstone on the southwest flank, into a block calcareous shale on the northeast side of the San Juan Basin.

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INTEGRATED RESULTS OF GEOLOGICAL, GEOPHYSICAL, AND REMOTE SENSING INTERPRETATION OF BASIN EVOLUTION, LITHOSTRATIGRAPHY, AND PRESENT STRUCTURE WITHIN THE GREATER BLACK MESA REGION, NORTHEASTERN ARIZONA

The U.S. Department of Energy (DOE) has instituted a basin-analysis study to encourage drilling by independent oil companies within the continental United States. The work is being performed at the National Institute for Petroleum and Energy Research (NIPER) by BDM Oklahoma, the manager of the facility for DOE. The Black Mesa region in northeastern Arizona (Figure 1-1) was selected by DOE for the initial NIPER-BDM Exploration and Drilling Group survey to develop prospects in unexplored/underexplored basins in the lower 48 states. The Black Mesa Basin is significantly underexplored, with only six wells having been drilled in the deep, central portion of the basin on the 1.5 million-ac Hopi Reservation, and an additional six wells on the flanks of the area. The Hopi wells were all drilled during 1965, and none had any follow-up testing or subsequent offsets. The study area includes the topographic Black Mesa (the site of the ancestral Hopi lands) and the geologically contiguous surrounding potential reservoirs beneath the southwestern parts of the Colorado Plateau. Much of this latter area underlies Navajo tribal lands.

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DOE/Fossil Energy's Drilling, Completion, and Stimulation RD&D: A Technologies/Products Overview

An overview of natural gas drilling, completion, and stimulation RD&D sponsored by the U.S. Department of Energy is reported in this paper. Development of high rate-of-penetration drilling systems and underbalanced drilling technologies are detailed among other RD&D activities. The overview serves as a technology transfer medium and is intended to accelerate the deployment of the products and technologies described.

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NATURALLY FRACTURED TIGHT GAS RESERVOIR

This report details the field work undertaken Blackhawk Geosciences and Lynn, Inc. during August 1994 to July 1995 at a gas field in the Wind River Basin in central Wyoming. The field surveys were performed for the Department of Energy, Morgantown Energy Technology Center, under Contract No. DE-AC21-94MC31224, "Naturally Fractured Tight Gas Reservoir Detection Optimization".  The work described herein consisted of four parts: -9C VSP in a well at the site: - Additional Processing of the previously recorded 3-D survey at the site -Multicomponent feasibility studies during the 3D P-wave survey on the site, and Minivibrator testing -Planning and Acquisition of a 3-D, 3-C seismic survey The objectives of all four parts were to characterize the nature of anisotropy in the reservoir. With the 9C VSP, established practices were used to achieve this objective in the immediate vicinity of the well. The additional processing of the 3- D uses developmental techniques to determine areas of fractures in 3-D surveys. With the multicomponent studies, tests were conducted to establish the feasibility of surface recording of the anisotropic reservoir rocks. The 3-D, 3-C survey will provide both compressional and shear wave data sets over areas of known fracturing to verify the research.

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ASSIST IN THE RECOVERY OF BYPASSED OIL FROM RESERVOIRS IN THE GULF OF MEXICO

During the past year, a report on the simulation work performed on the U-8 reservoir was completed. Upon completing the history match of the reservoir and the running of several predictive runs, evidence indicates the following: layers "A" and "B" of the U-8 sand are in communication; the given reservoir relative permeability data was not appropriate for the U-8 sand reservoir and the relative permeability's were modified to enable a history match to be obtained; the vertical permeability values were found to be within the accepted range for the Gulf of Mexico (O.lKx < Kz < 0.5Kx, with Kx = Ky) at 0.4 Kx; based on industry's desired design (water injection of 5100 BBL/D), the best possible production scenario is in the northeastern portion of the reservoir; if the water injection rate is doubled 10,200 MSTB/D, the additional oil recovery may be increased by 33% (1,214 MSTB) in the vertical well scenario and by 37% (1,320 MSTB) in the horizontal well scenario; by converting the production wells to water injection wells and drilling a horizontal production well in the north-central portion of the reservoir, the production obtained is approximately 90% of the production obtained from the northeastern portion of the reservoir at the same field injection rate. Also, modifications to handle steeply dipping reservoirs have been successfully implemented in the MASTER simulator and critical process parameter laboratory experiments and computer simulations of the experiments have been completed. In addition, development of predictive models for undeveloped oil and immiscible/miscible processes began. The methodology for determination of undeveloped potential has been completed. The design of the miscible and updip displacement models as well as the design of the economic and timing models is underway. The coding and calibration of the models began. Data validation, map measurements, model development and supporting cost data collection was in progress. The approach for the TORIS predictive modeling includes gathering raw data from MMS files, both electronic and hard copy; reducing the data to fit a simplified model of salt piercement reservoir geometry; redescribing the resource to accommodate known production behavior and certain geologic assumptions; and assessing the unrecovered oil potential of the redescribed resource under various economic and technologic scenarios.

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DEVELOPMENT OF A MEMBRANE-BASED PROCESS FOR THE TREATMENT OF OILY WASTE WATERS

The goal of this program was to develop an economical oily-water treatment system based on reverse-osmosis (RO) membrane technology. The RO system would be used to 1) reduce oil-production costs by reducing the volume of waste water for which disposal is required; 2) form the basis of a generic waste-water treatment system that can easily be integrated into oil-field operations, especially at production facilities that are small or in remote locations; and 3) produce water clean enough to meet current and anticipated environmental regulations. The specific focus of this program was to develop a hollow-fiber membrane module capable of treating oily waste waters. Typically, the organics in oily waste water swell or dissolve the materials used in conventional polymeric membranes and modules. Our goal was to develop hollow-fiber membranes and modules that were more solvent-resistant than conventional membrane modules. We successfully achieved this goal. During the course of this program, we developed thin-film-composite (TFC) membranes, which consisted of a solvent-resistant selective coating placed on a solvent-resistant hollow-fiber support. These TFC membranes were used in low cost, hollow-fiber modules, which were made using solvent-resistant components. The modules were tube-side-feed modules, in which the oily waste water travels down the _inside (lumen) of the hollow fiber. The selective coating allows water to pass freely through the wall of the fiber, but restricts the transport of oil and grease and some of the dissolved organics and salts in the feed. Using these modules, more than 90% of the oily waste water can be recovered as clean permeate (suitable for discharge), while the remaining 10% is removed as oily-water concentrate (which can be recycled for recovery of the oil or disposed of in an environmentally acceptable manner). During this program, we successfully fabricated membranes with high solvent resistance. The properties of these membranes showed little or no change when the membranes were soaked in pure solvents such as toluene or gasoline. The solvent-resistant modules developed in this program were successfully field-tested on actual oily-water streams. During demonstration tests, the modules were operated for more than 2000 hours. The tests showed the permeate produced by the modules was sufficiently clean to meet discharge regulations. With improvements in the pretreatment system, the technology developed in this program should be capable of maintaining high water fluxes and treating oily waters effectively.

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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 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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Improved Oil Recovery in Fluvial Dominated Deltaic Reservoirs of Kansas - Near-Term

Common oil field problems exist in fluvial dominated deltaic reservoirs in Kansas. The problems are poor waterflood sweep and lack of reservoir management. The poor waterflood sweep efficiency is due to 1) reservoir heterogeneity, 2) channeling of injected water through high permeability zones or fractures, and 3) clogging of water injection wells with solids as a result of poor water quality. In many instances the lack of reservoir management is due to lack of 1) data collection and organization, 2) integrated analysis of existing data by geological and engineering personnel, and 3) identification of optimum recovery techniques

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Post Waterflood C02 Miscible Flood in Light Oil Fluvial - Dominated Deltaic Reservoirs

Production from the Marg Area 1 at Port Neches is averaging 222 BOPD for this quarter. The production drop is due in part to mechanical problems and to poor sweep efficiency caused by water blockage that prevented the CO, from contacting new residual oil deeper in the reservoir. Alternating water and gas injection assisted to some extent in maintaining oil production and improved the reservoir yield by reducing the gas production. A workover was performed on well Kuhn #38 to correct failed gravel pack setting. Production from the well was restored to 60 BOPD. Plugging of the injection wells continue to be a problem, reducing the injection rate in critical areas of the reservoir, near well Kuhn #15R. Texaco drilled the well Polk B #39 to The Marg Area 3 reservoir to gain structural position based on the 3D seismic, and found the sand present as anticipated. However, the sand did not have any hydrocarbon accumulation. For this reason, Texaco will abandon testing the idea of utilizing CO, to accelerate the primary production rate and reduce water production and primary production cycle time, in the reservoir.

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Design and Implementation of a co2 Flood Utilizing Advanced Reservoir Characterization and Horizontal Injection Wells in a Shallow Shelf Carbonate Approaching Waterflood Depletion

The first objective is to utilize reservoir characterization and advanced technologies to optimize the design of a CO2 project for the South Cowden Unit (SCU) located in Ector County, Texas. The SCU is a mature, relatively small, shallow shelf carbonate unit nearing waterflood depletion. The second objective is to demonstrate the performance and economic viability of the project in the field. The work reported here is on the reservoir characterization and project design objective. This objective is scheduled to be completed in October of 1995 at which time work on the field demonstration phase is scheduled to begin.

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MODELING OF WELLBORE Stability

This report describes the status of BDM-Oklahoma's evaluation of models used in solving wellbore stability problem. The bulk of these problems involve shales, and shales makes up most of the formations drilled. These instabilities can be mechanical (shales are inherently weak), chemical (incompatibilities with drilling fluids), or most likely, a combination of the two. Most models of wellbore stability concentrate on the rock mechanics of shales. They attempt to calculate the mud weight needed to minimize spalling and other stability problems without exceeding the hydraulic fracture pressure. Chemical interactions are either not considered or dealt with very simplistically. Although much can be done in the laboratory, both from a rock mechanics and chemical interaction standpoint, it has been difficult to relate these to the wellbore, particularly while drilling (i.e., in real-time analysis).

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INDUSTRY STATE-OF-THE-ART IN UNDERBALANCED DRILLING

This report discusses the current state of drilling underbalanced by industry. Underbalanced drilling is generally achieved by introducing a gas into the drilling fluid. This can range from air drilling (no liquid) to aerated fluids containing only a small percent of gas. Much of the paper is dedicated to discussing the advantages and limitations. The principle advantages are increased productivity through minimizing formation damage and increased penetration rate. The main disadvantage is the absence of adequate modeling to achieve and maintain the underbalanced condition. This report also discusses the various methods of achieving an underbalanced condition.

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Analysis of U.S. Department of Energy's Oil and Gas Programs in Response to the National Petroleum Council Study on the RD&D Needs of  the Oil and Gas Industry

In August 1995, the Office of Fossil Energy (Fossil Energy) initiated an analysis of the Department of Energy's (DOE or the Department) Fiscal Year (FY) 1995 oil and gas research, development, and demonstration (RD&D) programs. The purpose of this analysis was to determine the degree to which DOE's programs address industry's priority technology needs as identified in the National Petroleum Council's (the Council or NPC) study entitled, "RD&D Needs of the Oil and Gas Industry" (August 1995).

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Analysis of the U.S. Department of Energy's Oil and Gas Programs

In August 1995, the Office of Fossil Energy (Fossil Energy) initiated an analysis of the Department of Energy's (DOE or the Department) Fiscal Year (FY) 1995 oil and gas research, development, and demonstration (RD&D) programs. The purpose of this analysis was to determine the degree to which DOE's programs address industry's priority technology needs as identified in the National Petroleum Council's (the Council or NPC) study entitled, "RD&D Needs of the Oil and Gas Industry" (August 1995). The Council is an advisory body to the Secretary of Energy on matters relating to oil and natural gas or the oil and gas industries. The Council's study provides a listing of 176 industry technology RD&D needs, of which 36 are designated as high priority. An overview of the Council's study, including its methodology and recommendations, is provided in this report. Based on this program analysis, the Department will examine all high priority technology areas to determine whether there is an appropriate Federal RD&D role under current Departmental policy, regulation, and statutory mandates. In an ongoing dialogue with the industry, DOE will redirect current programs, as appropriate to DOE's mission, and identify cooperative RD&D opportunities with industry in the high priority areas.

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STRATEGIES FOR RESERVOIR CHARACTERIZATION AND IDENTIFICATION OF INCREMENTAL RECOVERY OPPORTUNITIES IN MATURE RESERVOIRS IN FRIO FLUVIAL-DELTAIC SANDSTONES SOUTH TEXAS: AN EXAMPLE FROM RINCON FIELD, STARR COUNTY

Fluvial-deltaic sandstone reservoirs in the United States are being abandoned at high rates, yet they still contain more than 34 billion barrels of unrecovered oil. The mature Oligocene-age fluvial-deltaic reservoirs of the Frio Formation along the Vicksburg Fault Zone in South Texas are typical of this class in that, after more than three decades of production, they still contain 61 percent of the original mobile oil in place, or 1.6 billion barrels. This resource represents a tremendous target for advanced reservoir characterization studies that integrate geological and engineering analysis to locate untapped and incompletely drained reservoir compartments isolated by stratigraphic heterogeneities. The D and E reservoir intervals of Rincon field, Starr County, South Texas, were selected for detailed study to demonstrate the ability of advanced characterization techniques to identify reservoir compartmentalization and locate specific infield reserve-growth opportunities. Reservoir architecture, determined through high-frequency genetic stratigraphy and facies analysis, was integrated with production history and facies-based petrophysical analysis of individual flow units to identify recompletion and geologically targeted infill drilling opportunities. Each of the two reservoir intervals selected approximates a fourth-order genetic unit and contains four to six higher frequency genetic units that act as individual flow units. Flow units progress from aggradational fluvial (upper delta plain) settings at the base of the E interval through retrogradational, then progradational channel and delta front bar settings at the top of the E and base of the D intervals. Uppermost D units represent a return to aggradational fluvial reservoirs. Greatest heterogeneities and lowest recovery efficiencies exist in the strongly retrogradational and weakly progradational units. Estimates of original oil in place versus cumulative production in D and E reservoirs suggest that potential reserve growth exceeds 4.5 million barrels. Comparison of reservoir architecture and the distribution of completions in each flow unit indicates a large number of reserve-growth opportunities. Potential reserves can be assigned to each opportunity by constructing an SojZlh map of remaining mobile oil, which is the difference between original oil in place and the volumes drained by past completions. The methodology demonstrated in this study has direct application to other reservoirs in Rincon field, other fields in the Frio Fluvial-Deltaic Play of South Texas, and mature reservoirs across the U.S. formed in analogous depositional settings.

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Expansion Rate Effect on the Initial Stage of Gas Phase Formation in Supersaturated-binary Mixtures

The integral equation describing the nucleation and growth of bubbles in a supersaturated binary liquid mixture under constant expansion rate is considered. In case of macroscopically large number of microscopic nucleation sites, the solution is shown to exhibit weak dependence on the expansion rate in contradiction with experimental data. With few nucleation sites, the supersaturation extreme agrees with experimental data.

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ESTIMATES OF GAS RESOURCES IN OVERPRESSURED LOW-PERMEABILITY CRETACEOUS AND TERTIARY SANDSTONE RESERVOIRS, GREATER GREEN RIVER BASIN, WYOMING, COLORADO, AND UTAH

The Greater Green River basin of Wyoming, Colorado, and Utah contains large amounts of gas in overpressured low-permeability Cretaceous and Tertiary reservoirs. The stratigraphic sequence in which these reservoirs occur is as much as 14,000-ft (4,267-in) thick and includes the Lower Cretaceous Cloverly Formation through the lower Tertiary Fort Union Formation.

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