AndreaBozzo/ceres-open-data-index huggingface dataset:
GEOLOGY AND PETROLEUM OF THE MANCOS B FORMATION DOUGLAS CREEK ARCH AREA COLORADO AND UTAH

The Mancos B Formation is a complex of intimately interbedded and interlaminated claystone, siltstone, and fine sandstone formed in a marine environment about 100 miles east of the Emery shoreline. The lower Mancos B was deposited as east-west trending, northward prograding fore slope sets built on a sub-horizontal ocean floor; sandy facies are found as far north as Douglas Creek anticline but rapidly change to a shaly facies farther north. Deposition of the upper Mancos B began with an influx of sandy material, probably from the west, that filled an erosional (?) topographic low in the North Douglas Creek area and spread southward; some clastics continued to enter the area from the south or southwest. The formation is "sandiest" at Douglas Creek anticline, where it is about 500 feet thick, and "shaliest" in the southeast, where it can be over 1000 feet thick.

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LLL -GAS STIMULATION - PROGRAM

This report summarizes the research and  accomplishments of the LLL Gas Stimulation Program during the third quarter of FY 1977. Work has continued on the two theoretical models that simulate, respectively, the local and distance effects of .the hydraulic fracturing process. Application and analysis have indicated that for a penetrating fluid and stress intensity factor tends to decrease as the pore pressure increases. Laboratory fracturing experiments indicate that for no precracking the borehole, the hydraulic fluid pressure necessary to initiate a crack is relatively insensitive to the applied load on the block. Other laboratory experiments have been performed to test the sensitivity of the principal stress magnitudes on the fracture orientation. We have also completed a rock geometry and mechanics study of the Western tight gas sands. A summary of this study is included here and is being published under separate cover.

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PRELIMINARY REPORT: PETROLEUM GEOCHEMISTRY OF THE DENVER BASIN

Crude oil and shale samples from the Denver basin of Colorado, Wyoming, and Nebraska were analyzed using organic geochemical techniques to determine oil-source bed relationships.  In general, oils in Cretaceous reservoirs are compositionally similar throughout the basin and are geochemically dissimilar to the oil produced from Permian Lyons Sandstone. The Cretaceous oils are compared with hydrocarbon extracts from Cretaceous shales to determine the stratigraphic occurrence and regional distribution of petroleum source beds. The results show that oils produced from the Cretaceous Terry and Hygiene Sandstone Members of the Pierre Shale, "D", and "J" sandstone reservoirs have probably been derived from the Carlile, Greenhorn, Graneros, and Mowry Formations. The source bed for oil from the Lyons has not yet been identified. Samples of the Carlile-Greenhorn-Graneros-Mowry interval have been analyzed throughout the basin. Only samples from the basin-axis area contained hydrocarbon distributions similar to those Cretaceous oils. The occurrence of petroleum on the east flank of the basin, in light of the limited geographic distribution of effective source beds, indicates that extensive (as much as about 150 km) lateral migration has occurred. This suggests that an understanding of lateral migration pathways is important for petroleum exploration in the Denver basin.

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Carbon Dioxide Sources and Oil Fields in a Nine-State Area of the Southwest United States

Data on the prospective available CO2 in a nine-State area of the Southwest were collected from scattered sources and compiled to make the information readily available to operators who may be interested in using CO2 techniques for enhanced oilfield recoveries. Maps of the oilfields in the area studied are provided so that location of supply source can be related to possible point of use. The best potential sources of CO2 are flue gas from electric generating plants, flue gas from cement plants, output from ammonia plants and natural gas reservoirs. The CO2 sources are listed by states and includes the operator's name, location name, county, and average available amounts of CO2.

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Tertiary Oil Recovery By CO2 Injection

Operations during the first quarter of 1977 were severely hampered by the worst winter on record for the Northeastern United States. Natural gas curtailments to chemical plants caused CO2 to become unavailable for our project in early January. This situation remained until early March when warmer weather allowed the lifting of the curtailments. During this period water  injection was attempted to maintain reservoir pressure. However, these efforts were not successful due to constant freeze-ups and leaks

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Western Gas Sands Project Plan Document FY 1978

The Department of Energy (DOE) has embarked on a program to accelerate the development of domestic energy resources. One project under this program is the Western Gas Sands Project (WGSP) which is directed toward development of new or improved techniques for recovering natural gas from low permeability reservoirs currently not economic. The principal activities that  comprise this project are: Project Management Resource Assessment Research and Development by Energy Research Centers and National Laboratories Field Tests and Demonstrations

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EARLY CRETACEOUS MUDDY SANDSTONE DELTA OF WESTERN WIND RIVER BASIN, WYOMING

The Muddy sandstones in the western Wind River Basin were deposited in a thin, but well-developed delta system during Early Cretaceous Abian time. Open marine Skull Creek shales grade upward into the lower marine Muddy sandstones (Fig. 1).The Muddy sandstones in the western Wind River Basin were deposited in a thin, but well-developed delta system during Early Cretaceous Albian time. Open marine Skull Creek shales grade upward into the lower marine Muddy sandstones (Fig. 1). The depositional surface was raised to sea level by deposition of 65 feet of prodelta sediments and delta-front sandstones at the northwest seaward edge of the- delta. Progradation of delta plain deposits then covered the be delta-front sandstones. Rapid subsidence allowed preservation of mOBt Muddy sedimentary rocks in the northwest part of the study area, but a lesser rate of subsidence or slight uplift to the southeast allowed progressively deeper erosion, resulting in two intraformational unconformities. The lower marine deposits were eroded deeply by rivers of the delta plain and mOBt of these lower marine sedimentary rocks southeast of Lander were removed (D of Fig. 21. The delta plain was successively covered by two main facies: 11 fluvial channel sandstones and 2) flood plain deposits. The Fluvial sandstones, deposited in a northwest-flowing river system, terminate to the northwest (e of Fig. 2). The overlying flood plain deposits are truncated southeastward (upstream) (F of Fig. 2) by erosion at the base of the overlying transgressive beach deposits. Progressive onlapping by beach and nearshore deposits of the middle marine Muddy sequence subsequently buried the older delta system (Fig. l). The uniformity at the base of the beach deposits cuts progressively deeper into underlying delta plain deposits to the southeast, where reworked beach Bandstones were deposited directly on the fluvial sandstones of the delta plain. A second, or upper, marine sandstone and shale sequence buried the delta to the southeast. Northwest of line H (Fig. 2) the sandstones grade seaward into marine shales.

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Mineralogical analyses of drill core samples from Midlands Gas Corporation wells-- Federal 0370 No. 1 and Federal 2962 No. 1, Phillip s County, Montana

This report records the mineralogy of core samples from two wells in Phillips County, Montana. These wells are located in the Bowdoin gas field in north-central Montana. The gas is produced from low-permeability reservoirs at shallow depths (less than 610 m) over an area of 1554 km2 . This information is being released to aid in improving recovery technology and well log interpretation. We acknowledge the financial support of the Department of Energy Tight Gas Sands program.

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NIOBRARA GAS IN  EASTERN COLORADO AND NORTHWESTERN KANSAS

Natural gas from the Niobrara Formation was discovered in 1919 al the Beecher Island field in Yuma County, Colorado, but commercial development did not commence until 1972. There are now more than 30 fields located primarily in Yuma County, Colorado and Cheyenne County, Kansas. Biogenic gas is produced from chalk with high porosity but low permeability at the top of the Smoky Hill Chalk Member of the Cretaceous Niobrara Formation at depths ranging from 900 to 2800 feet. The producing area is on the eastern flank of the Denver basin and accumulations were normally on low relief anticlinal closures. The wells are stimulated with a foam fracturing treatment and will deliver from 20 to 300 MCFGPD. The Niobrara and other Upper Cretaceous chalks are considered to be prospective as shallow gas reservoirs over a large area of the Western Interior.

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A Review of Shallow-Shelf Carbonate Reservoirs in the United States

The DOE has used the information available in the Tertiary Oil Recovery Information System (TOruS) database to identify reservoirs with significant remaining production potential These reservoirs were grouped into classes having common geologic characteristics and ranked according to oil-in-place, recovery potential and risk of near-term abandonment. Such rankings were developed with the goal of prioritizing research efforts focused on recovering this resource. This report provides to the industry at large a review of background information regarding DOE's current understanding of the reservoirs known as shallow-shelf carbonates. It details information related to their geologic characterization, the improved recovery techniques having the greatest potential, and the principal impediments to increased production.

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Sedimentology and Stratigraphy of the Lower Eocene Wind River Formation, Central Wyoming

The fluvial tower Eocene Wind River Formation crops out throughout most of the Wind River Basin. The geology of the Wind River Formation is important from an economic point of view, as it is the host rock for important quantities of hydrocarbons and uranium. Soister (1968), Van Houten (1964), and others have written detailed accounts of the stratigraphy of the Wind River Formation in specific parts of the basin, and Keefer (1965a) has presented a more regional view. These works will provide a background for the sedimentologic and stratigraphic data and interpretations of this paper.

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Stratigraphy of the Lower Cretaceous J Sandstone, Boulder County, Colorado: A Deltaic Model

The J Sandstone is the uppermost formation of the Lower Cretaceous Dakota Group. In the Denver basin it is composed of a regressive sequence of deltaic sediments which entered the Cretaceous seaway from both the east and west. The J Sandstone exposed on   the western flank of the Denver basin in Boulder County in the Dakota hogback was derived from a western source.

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The Detection of Gaseous Hydrocarbon Accumulations by Seismic Interference Patterns and Lateral Velocity Variations

Seismic interference, or what is often called "noise," is recorded simultaneously with reflected energy and becomes an intrinsic part of a record section. The interference is generally from two sources; one generated near or at the surface by the energy source, and the other in the subsurface, returning a wave form known as a diffraction.

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Tertiary Oil Recovery By Co2 Injection

The objective of this field test is to evaluate and demonstrate the effectiveness of using CO2 injection to recover high gravity crude oil from shallow watered-out reservoirs. The estimated recovery potential from the flood pattern of six (6) acres is approximately 50,000 barrels. The work will be conducted in five (5) phases as follows:  Phase l--Preliminary Testing and Construction Water Injection, and Plant Construction Phase 2--Natural Gasoline Injection Phase 3--C02 Injection Phase 4--Carbonated Water Injection Phase 5--Water Injection

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Direct Coal Liquefaction Baseline Design and System Analysis Volume IIa Baseline Design

The strategy utilized to arrive at the Plant capacity is described below: The Bechtel/Amoco team in consultation with Hydrocarbon Research Institute (HRI) established the maximum size coal liquefaction train based on reactor design/fabrication/shipping limitations. The Maximum Plant capacity was then fixed at 61,945 BPSD of coal liquids (C, -850?F) based on the expected production capacity of five maximum size trains, each producing 12,389 BPSD. The Coal throughput was then calculated to match the above output, depending on the design basis yield furnished by Bechtel/Amoco team. Based on the above strategy, the total (5 trains) coal throughput capacity is 17,102 TPSD of moisture free (MF) coal or 15,140 TPSD of moisture and ash free (MAF) coal.

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Refining and Upgrading of Synfuels from Coal and Oil Shales by Advanced Catalytic Processes

Advanced commercial petroleum processing technology was employed in pilot plant facilities to produce transportation fuels from Paraho shale oil. Three likely refining routes were identified and demonstrated sufficiently to permit preparation of screening-type process designs and cost estimates: (1) hydrotreating followed by hydrocracking, (2) hydrotreating followed by catalytic cracking, and (3) coking followed by hydrotreating. In a fourth feasible alternative, raw shale oil was hydrotreated to produce a synthetic crude suitable for processing in an existing refinery. The key to successful shale oil refining is an effective initial hydrotreating step. This removes contaminants and permits the use of conventional hydrocracking or fluid catalytic cracking. Distillates from coking of raw shale oil also require subsequent hydrotreating to remove residual impurities and meet final product specifications. Refining costs to convert raw shale oil to transportation fuels were estimated to be about $8-$10/ barrel, depending upon the processing route and based on producing 100,000 BPCD of transportation fuels from a "grass roots" refinery located near a Rocky Mountain or Mid-Continent urban center. Costs are higher for smaller, remotely located refineries. Hydroprocessing of raw shale oil to produce a synthetic crude would cost about $6.50/barrel.

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DETERMINATION OF THE OPTIMUM  MASSIVE HYDRAULIC FRACTURING DESIGN FOR THE STIMULATION OF THE WASATCH AND MESAVERDE FORMATION

I. Natural Buttes No. 18 produced a total of 17,359 MeF in 31 days for an average flow rate of 560 MCFD. II. Natural  Buttes Unit No. 19 produced a total of 409 MCF at an average rate of 13 MCFD for 31 days. III. Natural Buttes Unit No. 14 produced a total of 16,361 MCF at an average rate of 528 ~CFD f,i 31 days. IV. Natural Buttes Unit No. 20 produced a total of 9877 MCF at an average rate of 319 MCFD for 31 days. v. Natural Buttes No. 21 is shut in, waiting on completion. VI. A. Natural Buttes Unit No. 22 is being cleaned out to PBTD and flowing to pit to unload frac fluids. B. Natural Buttes Unit No. 9 was cleaned out to 8959'PBTD and tubing and packer were run and set at 5492'. MHF was designed and is waiting to be traced. Rebids were received.

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DEPOSITIONAL ENVIRONMENTS AND DASGENSIS OF THE NUGGET SANDSTONE: SOUTH-CENTRAL WYOMING,NORTHEAST UTAH AND NORTHWEST COLORADO

Recent oil and gas discoveries in southwest Wyoming and northeast Utah have created considerable interest in the Nugget Sandstone. Successful exploration efforts require an accurate knowledge of several formation parameters, inching depositional environment and digenetic history. Information presented in this paper includes a study of the various types of cements in the Nugget and their chronology. Depositional environment is also discussed, along with its possible effect on diagenesis. This paper only briefly outlines the diagenetic and depositional framework of the Nugget, but as additional drilling takes place a more detailed history of the Nugget should emerge.

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DEPOSITIONAL ENVIROMENTS AND CORRELATION OF THE MESAVERDE FORMATION, WIND RIVER BASIN, WYOMING

The Mesaverde Formation is one of the major sedimentary deposits in the Rocky Mountain region. In the past few years the Mesaverde section has generated considerable interest as a source of energy resources in the basins of Wyoming,  The Upper Cretaceous Mesaverde Formation in the Wind River Basin is a marine, nonmarine. and transitional sequence of sandstones, siltstones. shales and coals. The sedimentation was characterized by pulses of regressions and transgressions resulting in intertonguing of marine and nonmarine deposits. Lenticular sandstones interstratified with shales and coals make correlations and interpretations of interrelationships of the intertonguing units difficult.

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HYDRCARBONS ACCUMULATIONS IN THE "D" SAND ADAMS AND ARAPAHOE COUNTIES, COLORADO

The Lower Cretaceous "D" sand in western Adams and Arapahoe Counties, Colorado. contains significant hydrocarbon reserves in stratigraphically trapped reservoirs. Reservoirs are developed in marine bar-type sand stones and in deltaic distributary channel sandstones. Trapping conditions include classical stratigraphy traps consisting of up-dip pinchout of sandstone, and more complex traps such as interchannel point bar porosity permeability pinchout flaps. Recognition of the environment of deposition of individual sand bodies combined with a practical mapping technique utilizing log shape/structure maps should lead to more discoveries in this area.

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Stratigraphy of Uppermost Cretaceous and Lower Tertiary Rocks of the Denver Basin

Uppermost Cretaceous and Lower Tertiary rocks total about  3,000 ft (g15 m) in thickness in the Denver basin. Sandstone, shale, and coal of the Upper Cretaceous  Laramie Formation are unconformably overlain by conglomerate and sandstone of the  Upper Cretaceous Arapahoe Formation overlying Denver Formation, which includes the  Cretaeous-Paileocene boundary, is composed of fine-lto coarse-andesitic sedimentary rocks and some coarse arctic beds. It includes inlerbedded carbonaceous shales and lignites throughout most of the basin. A mappable contact separates the Denver from the overlying Dawson Arkose. The lower member of the Dawson, of Isle Paleocene aye, is lenticular and is composed mainly of fine to coarse arkoses with Some aridesilic sedimentary rocks. It may be equivalent to the Green Mountain Conglomerale (Paleocene), which is composed of rocks with similar Lithology. The main body of the Dawson, composed mostly of coarse arkoses and conglomerate, is of Eocene age and overlies a distinctive thick paleosol throughout most of the basin.

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Application of Remote Sensing Studies to the Interpretation of Fracture Systems and Structural Styles in the Plateau Regions of Eastern Kentucky, Southwestern Virginia, and Southwestern West Virginia for Application to Fossil Fuel Extraction Processes.

Much of the world's mineral wealth is produced from natural rock fractures. For example, many of the low-temperature hydrothermal mineral deposits--primarily lead, zinc, and copper--are in crevices in natural fracture systems. Often these deposits are concentrated where fracture permeability has allowed water to dissolve away some of the parent rock. Subsequently, the fractures became avenues of permeability which allowed mineral bearing fluids to migrate and collect .

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DETERMINATION OF THE OPTIMUM MASSIVE HYDRAULIC FRACTURING DESIGN FOR THE STIMULATION OF THE WASATCH AND MESAVERDE FORMATION

During November 1977, the following work was accomplished: 1. Natural Buttes Unit No. 18 produced a total of 18,092 HCF in 30 days for an average flow rate of 603 HCFD. II. Natural Buttes Unit No. 19 produced at an average rate of 17 HCFD for 17 III. Natural Buttes Unit No. 14 produced at an average rate 0 E 562 HCFD for 30 days. IV. Natural Buttes Unit No. 20 produced at an average rate of 653 Hem for 18 days. V. Natural But.tes Unit No. 21 is shut in, waiting on cased hole logging. VI.  A.. Natural Buttes Unit No. 22 was traced on November 21, 1977.  b. Natural Buttes Unit No.9 was cleaned out to 8959 PBTD and tubing and packer were run and set at Sl.92'. NHF was designed and is waiting to be traced. Bids were received and are being evaluated.

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STRUCTURAL RESPONSE GOVERNING HYDRAULIC FRACTURING OPERATIONS I N ROCK MEDIA

This report describes analytical and experimental simulations of structural responses associated with hydraulic fracturing operations in rock media. The work was sponsored by Sandia Laboratories, ERDA under Contract No. 63-4997 and was performed in conjunction with staff from the Morgantown Energy Research Center. M r . H. H. Patterson served as Technical Monitor for Sandia with technical consultation provided by Mr. . Richard Hay and Mr. Jack Hinde.

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EXPLOSIVE FRACTURING DEMONSTRATION HAMPSHIRE GAS COMPANY WELL NOS. 10 & 18

In April 1974 Hampshire Gas Company entered into a Cooperative Agreement with the U. S. Bureau of Mines to participate in an explosive fracturing experiment. Hampshire's responsibilities under the agreement were to furnish three wells in the Augusta-Little Capon Field for the demonstration and to have a representative available for consultation during all phases of the test. In order to implement the Cooperative Agreement, Hampshire further executed a Cost-Reimbursement contract with the Bureau in August 1974 to provide the preparatory service work prior to the explosive placement and detonation, provide the services necessary to clean out each well after the test and to accomplish the production evaluation before and after the test on each well. This report is a summary of the work accomplished by Hampshire in the discharge of its obligations under the above agreement.

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Phase II Report and Second Monthly Technical Letter Report

Production testing of the Phase II experiment in the Pinedale Unit No.5 well continued throughout the month of November, 1975. In addition, (i) wireline logging was performed to determine sand level in the wellbore and which of the sandstones fractured were contributing to production, (ii) graphical presentations of data obtained during well cleanup were prepared and (iii) the quantity of sand recovered was determined. These activities are discussed in detail under headings which follow.

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FIRST MONTHLY TECHNICAL LETTER REPORT

Technical results prior to contract award consist of hydraulic fracturing of Stage 1 in the depth interval  between 10,950 feet and 11,190 feet in the Pinedale Unit No. 5 well, production testing of that stage and design of the next field experiment. Details of the Stage 1 experiment will be presented in a Phase Report covering that experiment and are reflected herein only to the extent that such details influence design of the second experiment. Various considerations in design of the second experiment are reflected under headings to follow.

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ECOLOGICAL CONSIDERATIONS  FOR PROJECT WAGON WHEEL AND HYDRAULIC FRACTURING ACTIVITIES PHASE Il(a): ANNUAL SUMMARY REPORT FOR 1974

This report summarizes those activities of the Team during 1974 which were not completed in time to include in the Phase I Report (PNE-WW-35) which appeared in June 1974. This document contains data and observations from the vegetation, aquatic, and mammalian studies. Most of the data are for the purpose of pre-event documentation for Project Wagon Wheel. Some additional information is presented which was gathered to document ecological impacts of hydraulic fracturing experiments in the Pinedale Unit near the Wagon Wheel Site. The main intent of this report is that of documentation rather than interpretation. Appropriate efforts toward interpretation of documentary information will be made if and when warranted by resource exploitation in or near the Pinedale Unit. Avian studies by W. C. Hanson during 1974 were completed in time for incorporation into the Phase I report and thus are not included herein.

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