AndreaBozzo/ceres-open-data-index huggingface dataset:
ADVANCED RESERVOIR CHARACTERIZATION IN THE ANTELOPE SHALE TO ESTABLISH THE VIABILITY OF CO2 ENHANCED OIL RECOVERY IN CALIFORNIA?S MONTEREY FORMATION SILICEOUS SHALES

The primary objective of our project was to conduct advanced reservoir characterization and modeling studies in the Antelope Shale. Work was subdivided into two phases or budget periods. The first phase of the project would focus on the application of a variety of advanced reservoir characterization techniques to determine the production characteristics of the Antelope Shale reservoir. Reservoir models based on the results of the characterization work would then be used to evaluate how the reservoir would respond to enhanced oil recovery (EOR) processes. The second phase of the project would be to implement and evaluate an EOR pilot in Buena Vista Hills Field. A successful project would demonstrate the economic viability and widespread applicability of CO, flooding in siliceous shale reservoirs of the San Joaquin The primary objective of this research is to conduct advanced reservoir characterization and modeling studies in the Antelope Shale reservoir. Characterization studies will be used to determine the technical feasibility of implementing a CO2 enhanced oil recovery project in the Antelope Shale in Buena Vista Hills Field. The Buena Vista Hills pilot CO2 project will demonstrate the economic viability and widespread applicability of CO2 flooding in fractured siliceous shale reservoirs of the San Joaquin Valley. The research consists of four primary work processes: Reservoir Matrix and Fluid Characterization; Fracture Characterization; Reservoir Modeling and Simulation; and CO2 Pilot Flood and Evaluation. Work done in these areas is subdivided into two phases or budget periods. The first phase of the project will focus on the application of a variety of advanced reservoir characterization techniques to determine the production characteristics of the Antelope Shale reservoir. Reservoir models based on the results of the characterization work will be used to evaluate how the reservoir will respond to secondary recovery and EOR processes. The second phase of the project will include the implementation and evaluation of an advanced enhanced oil recovery (EOR) pilot in the United Anticline (West Dome) of the Buena Vista Hills Field.

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Reservoir Characterization Of The Mississippian Ratcliffe, Richland Co., Montana, Williston Basin

This topical report is a compilation of characterizations by different disciplines of the Mississippian Ratcliffe in portions of Richland Co., MT. Goals of the report are to increase understanding of the reservoir rocks, oil-in-place, heterogeneity and methods for improved recovery. The report covers investigations of geology, petrography, reservoir engineering and seismic. The Ratcliffe is a low permeability oil reservoir which appears to be developed across much of the study area and occurs across much of the Williston Basin. The reservoir has not been a primary drilling target in the study area because average reserves have been insufficient to payout the cost of drilling and completion despite the application of hydraulic fracture stimulation. Oil trapping does not appear to be structurally controlled.

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Advanced Reservoir Characterization in the Antelope Shale to Establish the Viability of c02 Enhanced Oil Recovery in California's Monterey Formation Siliceous Shales

The primary objective of this research is to conduct advanced reservoir characterization and modeling studies in the Antelope Shale reservoir. Characterization studies will be used to determine the technical feasibility of implementing a CO2 enhanced oil recovery project in the Antelope Shale in Buena Vista Hills Field. The Buena Vista Hills pilot CO2 project will demonstrate the economic viability and widespread applicability of CO2 flooding in fractured siliceous shale reservoirs of the San Joaquin Valley. The research consists of four primary work processes: Reservoir Matrix and Fluid Characterization; Fracture Characterization; Reservoir Modeling and Simulation; and CO2 Pilot Flood and Evaluation. Work done in these areas is subdivided into two phases or budget periods. The first phase of the- project will focus on the application of a variety of advanced reservoir characterization techniques to determine the production characteristics of the Antelope Shale reservoir. Reservoir models based on the results of the characterization work will be used to evaluate how the reservoir will respond to secondary recovery and EOR processes. The second phase of the project will include the implementation and evaluation of an advanced enhanced oil recovery (EOR) pilot in the United Anticline (West Dome) of the Buena Vista Hills Field.

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Stratigraphic-Trap Classification

A trap for hydrocarbons requires the simultaneous  existence of (a) a reservoir, (b) on isolated region  of low potential in the reservoir, and (c] a barrier seal) with high enough entry pressure to retain a commercially producible volume hydrocarbons.  Three kinds of traps exists structural, stratigraphic, and hydrodynamic. All three kinds have a reservoir bounded by 1:1 barrier but differ in what causes the isolated area of low potential. In classification of hydrocarbon accumulations, the conditions that determined the present location of the accumulation should be used where they can be ascertained.

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Stratigraphy and Oil and Gas Production of Northwest New Mexico

This paper is a summary of the stratigraphy of the hydrocarbon-producing rocks of northwestern New Mexico and includes a discussion of the production from each of these rock units. (The reader is urged to refer to the time-stratigraphic nomenclature chart of the San Juan Basin by Molenaar, elsewhere in this volume, as a visual aid to the stratigraphic discussion in this report.) In addition, the most significant, recent stratigraphic references for each of the producing units are listed and discussed.

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Stratigraphy of West-Central New Mexico

West-central New Mexico, Fig. 1, is a relatively remote area, with a small population engaged mostly in ranching. South of Grants and Gallup, known economic mineral deposits are virtually nonexistent. Fluorite is mined in the Zuni Mountains, lead and zinc is still being recovered from the Magdalena Mountains, and salt continues to be harvested at Zuni Salt Lake.

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Summary of Gas Production Data for Wells Producing from Coal Seams and/or Tight Formations in Colorado, Montana, New Mexico, Utah, and Wyoming

In 1978, the Natural Gas Policy Act (NGPA) was enacted t o introduce measures which would increase the supply of natural gas and provide a gradual transition for the deregulation of natural gas through the use of price incentives and decontrol of gas prices. . Higher allowable prices were provided for new, high-cost, and stripper well gas to encourage exploration of these reserves(Tobin, Shambaugh, and Van Wagener 1989) . Table 1 lists the new, high-cost, and stripper well section-categories as defined under NGPA by the Federal Energy Regulatory Commission (FERC) .

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Appendix 3 Rock Island #4-H Site Characterization Report - Phase 3

The Greater Green River Basin (GGRB) of Wyoming (Fig 1) has produced abundant oil and gas out of multiple reservoirs for over 60 years, and large quantities of gas remain untapped in tight gas sandstone reservoirs Recent gas resource estimates for low permeability Cretaceous and Tertiary reservoirs in the GGRB range from 1,968 TCF in place (the Scotia Group) to 5,064 TCF in place (U S Geological Survey) (DOE Topical Report by the Scotia Group, 1993) Current activity, including the Greater Green River Basin Production Improvement Project, is focusing on ways to convert this vast resource into economically recoverable gas

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The Bisti Area, San Juan County, New Mexico

The Bisti area in central San Juan County, New Mexico, is on the south flank of the San Juan Basin. Production is from the Gallup sandstones and siltstones, Mesaverde group of Upper Cretaceoils age. Accumulation of oil and gas in the Bisti area is controlled by stratigraphic entrapment without structural closure.

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The Construction and Evaluation of an Improved Pressure System

An improved pressure coring system is necessary for the accurate determination of the true fluid content of oil and gas reservoirs. This is particularly important in those fields being planned for secondary or tertiary recovery programs. Two major areas for improvement have been considered. Bit design and coring fluids. Specialized bits have been designed and fabricated to achieve a high penetration rates and to reduce the contact of well bore fluids with the core. Water based coring fluids contaminating polymers and selected bridging particles have been laboratory tested, under simulated downhole conditions, to effect reduced core washing. These fluids are intended to be stored in the core retriever to lubricate and cool the portion of the bit  that is in contact with the core. Presently, these two features are  being incorporated into an existing pressure coring system, and upcoming field test plans will be discussed.

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CHARACTERIZATION OF FRACTURED RESERVOIRS USING STATIC AND DYNAMIC DATA: FROM SONIC AND 3D SEISMIC TO PERMEABILITY DISTRIBUTION

In low porosity, low permeability zones, natural fractures are the primary source of permeability affecting both production and injection of fluids. The open fractures do not contribute much to porosity, but they provide an increased drainage network to existing porosity. They also may connect the borehole to remote zones of better reservoir characteristics. An important approach to characterizing the fracture orientation and permeability of reservoir formations is one based on the effects of such conditions on the propagation of acoustic and seismic waves in the rock.

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The Frontier Formation in the Northwestern Wyoming and Adjacent Areas

A stratigraphic study of the Cretaceous Frontier Formation in the vicinity of Heart Mountain in the Big Horn Basin near Cody, Wyoming. and the Bridger Mountains on the western margin of the Crazy Mountains Basin in Montana has recently been completed. The formation is about 525 feet thick and consists of marine, deltaic, and lagoon sediments. It overlies the Mowry Shale Formation and is overlain by the Cody Shale Formation. A basal marine sandstone unit and a carbonaceous shale and mudstone facies have been mapped. The formation was deposited by progradation of sediment across south central Montana, southeastern Idaho, and northwestern Wyoming. Movement along major Precambrian fault systems may have displaced basement structures sufficiently to influence the progradation depositional process.

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The Gallup Sandstone as Exposed in the Western Part of the San Juan Basin

The Gallup sandstone has, with the discovery of significant quantities of oil and gas therein, attained a position of particular interest among the Cretaceous  sandstone units of the San Juan Basin. There have been many penetrations of the Gallup sandstone in the Bisti-Blackrock trend and much is known of the reservoir and subsurface lithologic characteristics of this unit. The purpose of this paper is to present briefly some of the features of the Gallup as observed in the outcrop on the western side of the San Juan Basin, and to discuss progressive changes in it from south to north.

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The Gallup Sandstone, its Age and Stratigraphic Relationships South and East of the Type Locality

The Gallup sandstone, the basal formation of the Mesaverde group in northwestern New Mexico (Beaumont, Dane, and Sears, 1956) was named, as the Gallup sandstone member of the Mesaverde formation (Seacs, 1925), from the town of Gallup, part of which is built upon its uppermost bed of sandstone. The complete section of Gallup sandstone is conspicuously and typically exposed along the Hogback three miles east of the center of town. As with the other formations of the Mesaverde group, the details of the stratigraphic relationships of the Gallup sandstone reveal the conditions of its deposition as port of the sequence of beds laid down during the alternating transgressions and regressions of on Arctic-connected late Cretaceous sea. The intertonguing relationships of the rocks of the Mesaverde group and the development of the concept that these relationships were brought about by brood oscillations of the strand line are given in the classic papers of Sears, Hunt, and Hendricks, 1941, and Pike, 1947. The present paper summarizes some new supplementary facts on the thickness, faunas, and intertonguing relationships of the Gallup sandstone and the overlying and underlying formations in the outcrop area in the vicinity of Gallup and in the region to the south and east. It is neither systematic nor complete, but represents a progress report on a continuing, through intermittent, study of these rocks by several members of the staff of the U. S. Geological Survey

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The Laney Member of the Green River Formation, Sand Wash Basin, Colorado, and its Relationship to Wyoming

The Laney Member of the Green River formation is a sequence of Eocene age rocks which are found in the southwest quarry of Wyoming and parts of northwest Colorado. In general, the Laney crops out along the margins of the Green River, Great Divide, Washakie and Sand Wash Basins of Wyoming and Colorado. The Laney is primarily a carbonate shale section which was deposited in or around ancient Lake Gosiute. Time transgressive sequences within the Laney Member of the Green River Formation indicate that ancient Lake Gosiute migrated into the study area late in its history and eventually terminated there. The termination of Lake Gosiute was preceded by progradation, freshening, and the development of an outlet. Through these processes, the Laney sediments in this area acquired unique lithologic, mineralogic and paleontologic characteristics relative to Laney rocks elsewhere. Two specific mineralogic characteristics which are unique to the area are the presence of cristobalite in some units, and the absence of evaporite minerals. The most striking lithologic difference between the Laney rocks of Wyoming and the Laney rocks of Colorado is the overall abundance of non-kerogeneous shales in Colorado. The lithologic, mineralogic and paleontologic characteristics and the cyclic nature of these characteristics are typical of playa-lahe deposition. In summary, the Laney rocks of Wyoming were  deposited in a large, penesaline playa lake; whereas, the Laney rocks of northwest Colorado were deposited in a much smaller and relatively fresher water lake. Since the Laney rocks of Wyoming and Colorado were deposited in the same lake, many Laney stratigraphic units cross time lines. The Laney rocks of northwest Colorado, therefore, represent the final stages of deposition in Eocene Lake Gosiute.

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The Stratigraphic and Sedimentologic Framework of the Green River Formation, Wyoming

During deposition of the Green River Formation, ancient Lake Gosiute started as a fresh-water lake, then evolved to a saline, alkaline lake and finally ended as a fresh-water lake. This evolution reflects the change from a closed-basin hydrologic regime to an open-basin hydrologic regime. As a result, sedimentation in the Lake Gosiute system was strongly influenced by the relationship between evaporation and inflow of water into the basin. In the Green River Formation, stratification sequences, sedimentary structures, and mineralogy of lithofacies provide important insights into the evolution of the system and into the competing factors that determined the type of sediment accumulated in the lake and fringing environments. Carbonate sedimentation was strongly influenced by lacustrine transgressions and regressions across a very low topographic gradient. Terrigenous rocks reflect progradation of beach and deltaic shorelines during wetter climatic intervals when detritus that had been produced and stored in upland areas during preceding drier intervals was transported to the lake.

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SUCTION PULSE DRILLING SYSTEM

An ideal drilling system would create a low-pressure region that is limited to the hole bottom while normal or overbalanced conditions are maintained above the bit to control formation fluids. The HydroPulse system shown in Figure 1 provides a means of generating intense cyclic suction pressure pulses that overcome the effects of borehole pressure and increase drilling penetration rate in deep formations. This system would be mounted on a conventional drill string and powered by mud hydraulics. The bottomhole assembly is compact and the system is compatible with downhole motors. The suction pulses could be used to enhance the penetration of conventional roller-cone, PDC or diamond bits. In many situations, such as horizontal drilling, it is difficult to apply a high mechanical thrust to the bit. The hydraulic thrust generated by a suction pressure pulse provides a means of drilling with minimal applied thrust. The suction pulse generator could also be used as a downhole seismic source or for a variety of workover operations such as removal of fines from damaged formations.

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The Dakota Sandstone and Mancos Shale in the Gallup Area

During the writers'examination of the intertonguing relations of the Gallup sandstone and the Moncos shale in the Hogback east and southeast of Gallup, several stratigraphic sections of the Mancos shale and Dakota sandstone were measured to furnish a supplemental datum against which to gauge lateral changes in the Gallup sandstone. The information thus incidentally obtained is summarized here and gives a more complete picture of the Mancos and Dakota of this area than has been heretofore published.

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NATURALLY FRACTURED RESERVOIRS: OPTIMIZED E&P STRATEGIES USING A REACTION-TRANSPORT-MECHANICAL SIMULATOR IN AN INTEGRATED APPROACH

Major accomplishments of this project occurred in three primary categories: 1) Fractured Reservoir Location and Characteristics Prediction for Exploration and Production Planning, 2) Implications of Geologic Data Analysis and Synthesis for Exploration and Development Programs and, 3) Fractured Reservoir Production Modeling.

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RESTORED DRILL CUTTINGS FOR WETLANDS CREATION: RESULTS OF A TWO YEAR MESOCOSM APPROACH TO EMULATE FIELD CONDITIONS UNDER VARYING HYDROLOGI REGIMES

It is well documented that Louisiana has the highest rate of wetland loss in the United States. Deep-water channel dredging and leveling of the Mississippi River since the 1930s have interrupted the natural delta cycle that builds new marshes through sediment deposition. Several sediment diversion and hydrologic restoration projects are currently in various stages of implementation under the Coastal Wetlands Planning, Protection, and Restoration Act (CWPPRA 1993). Many of the areas that are subsiding and deteriorating are isolated from riverine sediment sources; therefore alternative methods to deposit sediment and build marshes must be  implemented. This project demonstrates that the earthen materials produced when drilling oil and gas wells can be used as a suitable substrate for growing wetland plants. Drilling fluids (muds) are used to lubricate drill bits and stabilize the earth around drill holes and become commingled with the earthen cuttings. Two processes (referred to in this report as A and 8) have been reported to restore drill cuttings to acceptable levels by removal of any toxic components found in drilling muds. The main objective of this project was to assess the potential of drill cuttings processed by these two methods in terms of their ability to support wetland vegetation and potential toxicity. It was our belief that if processed drill cuttings can be shown to pose no environmental hazard, support  wetland vegetation, and compare favorably in cost to their current disposal, then their use in wetland creation and restoration projects should be considered.

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IMPROVED OIL PRODUCTION USING ECONOMICAL BIOPOLYMER-SURFACTANT BLENDS FOR PROFILE MODIFICATION AND MOBILITY CONTROL

A two-year research project funded by the United States Department of Energy (DOE) has identified new materials for use in oil field production technology. The program,  funded through a subcontract to BDM Oklahoma, identified these new materials found to be effective alternates to partially hydrolyzed polyacrylamides, copolymers, and xanthan gum polymers as water shutoff agents in fractures and in matrix flow configurations. In the past, the oil industry has found that poor injectivity and questionable stability of starch products prevented their use in profile control applications. However, in recent years, the demands of the oil and gas drilling industry have led to the development of new modified starches for drilling, drill-in, and completion fluids. The properties of the new products lend themselves to applications in improved recovery. Scientists from Prairie View A&M University and Texas A&M University have found that chemically modified starches have properties suitable for improved recovery technology. The materials, derived from inexpensive agricultural products, do not hydrolyze in harsh saline environments, are made more resistant to biodegradation, and because of their wide spectrum of molecular weight distributions can be tailored to specific lithologies. The development of new materials with superior functionality and reliability has been an important technological advance that can significantly increase oil and gas reserves, and reduce production costs. Among the various applications where modified starches were tested, two areas were identified with significant promise for improvement in technology, specifically (1) low temperature environmentally approved gel packages and (2) high temperature delayed gel packages. Modified starches offer an alternative to currently used  polyacrylamide, particularly for lower temperature systems, because of faster reaction times and adequate retention properties in porous media and in fractured core systems. Such systems compare favorably to commercially available systems used in soil consolidation and soil barrier treatments and are environmentally safe as well. Likewise, the program has identified starch materials that offer advantages in high temperature delayed gel applications. Delayed gel times are essential in high temperature applications because of the difficulty in placing gelant materials in formations where temperature accelerates reaction rates and gel times. Currently, the standard practice is to use retarding agents so that systems can be placed in reservoirs. The principal investigators for the research effort are Dr. Jorge Gabitto of Prairie View A&M University and Dr. Maria Barrufet of Texas A&M University. The work was supported in part by grants from Chemstar Inc. and Staley Manufacturing Inc.

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