AndreaBozzo/ceres-open-data-index huggingface dataset:
FINAL REPORT ROCK FRAGMENTATION RESEARCH AND DEVELOPMENT PROJECT

"The Rock Fragmentation Project was the first phase of a proposed four phase program to investigate the feasibility of using modified in situ recovery of oil from oil shale, The Phase I project of the program was designed to determine the techniques required to fragment the shale for in situ retorting. Phase I was a 23 month effort sponsored by: Cities Service Company, Getty Oil  Company, Mobil Research and Development Company, Phillips Petroleum Company, Sohio Shale Oil Company, and Sunoco Energy Development Company.  The overall program goal is to develop techniques that will lead to predictable and economic recovery of oil from oil shale by a modified in situ process. To achieve this goal, the Phase I project was directed to specific research efforts designed to develop an understanding of and to develop a predictive capability for in situ oil shale fragmentation. These research efforts include: stress wave propagation characteristics of oil shale; oil shale characteristics which control fracture and fragmentation; explosive characteristics which control fracture and fragmentation; geometric characteristics which control fracture and fragmentation; and predictive capabilities for preretort fragmentation design, given site specific geological features and material properties."

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STEAMFLOOD EXPERIMENT IN A UTAH TAR SAND

The first Laramie Energy Technology Center steam flood experiment in a Utah Tar Sand, LETC TS-1S, was conducted in the Northwest Asphalt Ridge deposit located near Vernal, Utah. Following completion of construction n April 1980, steam injection was initiated in the center well of two concentric inverted five spot patterns. The zone chosen for the experiment was a 45 foot (14 m) thick sandstone in the Rimrock Member of the Mesavarda Formation. The pattern area was 0.25 acres (1012 m^2) and contained a 12k API (986 kd/m^3) bitumen with a viscosity greater than 10^6 cantipoise (10^3 Pa.s) at reservoir conditions. The average oil saturation was 8.9 percent of the pore volume. During the 160 days of operation, 65,700 barrels (10.4 dem^3) of water equivalent steam were injected at 360 to 530 peig (2.5 to 3.7 MPa) and 180 to 650 BPD (29 to 103 m^3/d). Total production during the test amounted to 1,150 barrels (183 m^3) of oil and 6,250 barrels (994 m^3) of water.

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D-SERIES SUMMARY REPORT ROCK FRAGMENTATION RESEARCH AND DEVELOPMENT PROJECT

"The overall program goal is to develop techniques that will lead to predictable and economical recovery of oil from oil shale by a modified in situ process. To achieve this goal, the Phase I project was directed to specific research efforts defined to develop an understanding of and to develop a predictive capability for in situ oil shale fragmentation. These research efforts include: stress wave propagation characteristics of oil shale; oil shale characteristics which control fracture and fragmentation; explosive characteristics which control fracture and fragmentation;  geometric characteristics which control fracture and fragmentation;  and predictive capabilities of preretort fragmentation design given local geological features and material behavior.  A detailed test plan to evaluate the fragmentation characteristics is presented in Table 1."

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C-SERIES SUMMARY REPORT ROCK FRAGMENTATION RESEARCH AND DEVELOPMENT PROJECT

"The overall program goal is to develop techniques that will lead to predictable and economical recovery of oil from oil shale by a modified in situ process. To achieve this goal, the Phase I project was directed to specific research efforts defined to develop an understanding of and to develop a predictive capability for in situ oil shale fragmentation. These research efforts include: stress wave propagation characteristics of oil shale; oil shale characteristics which control fracture and fragmentation; explosive characteristics which control fracture and fragmentation;  geometric characteristics which control fracture and fragmentation;  and predictive capabilities of preretort fragmentation design given local geological features and material behavior.  A detailed test plan to evaluate the fragmentation characteristics is presented in Table 1."

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B-SERIES SUMMARY REPORT ROCK FRAGMENTATION RESEARCH AND DEVELOPMENT PROJECT

"The overall program goal is to develop techniques that will lead to predictable and economical recovery of oil from oil shale by a modified in situ process. To achieve this goal, the Phase I project was directed to specific research efforts defined to develop an understanding of and to develop a predictive capability for in situ oil shale fragmentation. These research efforts include: stress wave propagation characteristics of oil shale; oil shale characteristics which control fracture and fragmentation; explosive characteristics which control fracture and fragmentation;  geometric characteristics which control fracture and fragmentation;  and predictive capabilities of preretort fragmentation design given local geological features and material behavior.  A detailed test plan to evaluate the fragmentation characteristics is presented in Table 1."

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A-SERIES SUMMARY REPORT ROCK FRAGMENTATION RESEARCH AND DEVELOPMENT PROJECT

"The overall program goal is to develop techniques that will lead to predictable and economical recovery of oil from oil shale by a modified in situ process. To achieve this goal, the Phase I project was directed to specific research efforts defined to develop an understanding of and to develop a predictive capability for in situ oil shale fragmentation. These research efforts included evaluation of: stress wave propagation characteristics of oil shale; oil shale characteristics which control fracture and fragmentation; explosive characteristics which control fracture and fragmentation; geometric characteristics which control fracture and fragmentation; predictive capabilities of preretort fragmentation design given local geological features and material behavior.  A detailed program plan to evaluate the fragmentation characteristics is presented in Table 1 and Figure 1.  The observation and discussion presented encompass the activities of the A-Series tests conducted at the Anvil Points Mine near Rifle, Colorado."

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A PLANNING DOCUMENT EVALUATING SHALE OIL MARKETING AND TRANSPORTATION OPTIONS

Two discrete levels of shale oil production were evaluated during the course of the investigation. The first was a 15,000-barrel-per-day production level from the single-module demonstration program between 1987 and 1990. The second was a full-scale commercial production level of 50,000 barrels per day commencing in 1990. Also assumed were two levels of total industry production during there time periods; a total of 300,000 barrels per day from 1987 to 1990, and 400,000 barrels per day thereafter. These assumptions were provided by The Superior Oil company based on its own project schedule and industry forecasts.

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Monitoring of Emissions from an In Situ Coal Gasification Experiment

"Product gases produced from an in situ coal gasification experiment conducted by the Laramie Energy Research Center at Hanna, Wyoming, have been monitored for particulate matter content and the concentrations of fourteen trace components. Six monitoring  periods for each component were conducted at the wellhead during distinctly different operating conditions in order to determine concentration changed during different times in the lifetime of a two-well system.  The results of the monitoring will be presented. The implications of the monitoring with regard to utilization of low-Btu gas produced by UCG will also be discussed."

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REFINERY TREATING PLANT OPERATIONS RUN NO. 10

"This report covers treating plant run No. 10 during which  gasoline produced by thermal cracking of (1) N-T-U shale oil and (2)  coker heavy gas oil from N-T-U shale oil were processed. The primary, objective of this run was to determine the minimum 66°Be sulfuric acid treatment necessary to produce a treated gasoline of satisfactory gum content, color, and storage stability. The finished gasoline did not meet minimum storage stability requirements."

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REFINERY TREATING PLANT OPERATIONS RUN NO. 13

"During treating run No. 13, which was made in May, 1951, light gas oil (395 to 658 F. boiling range) produced by coking crude N-T-U shale oil was acid treated and inhibited to produce Diesel fuel for an extended test  by the Denver Rio Grande Western Railroad in a switching locomotive. Additional fuel for use in Diesel equipment at the Rifle station also was produced in the run. The light gas oil was treated in three steps ,consisting of (1) tar-acid  and tar-base removal, (2) acid treatment with 16.3 pounds of 66 Be'sulfuric acid per barrel of raw oil charged, and (3) an additional acid treatment using 3.2 pounds of sulfuric acid per barrel of raw oil.  The oil thus treated ,was inhibited with 0.05 volume percent of National Aluminate Corporation X-159 inhibitor.  An over-all product yield of 72.7 volume percent was obtained.  The Denver & Rio Grande Railroad used 4,643 gallons of the shale-oil Diesel fuel in a switch engine for a test operation of 751 hours duration.  The fuel was found to be satisfactory in all respects. Further, no difficulty  of any kind was encountered when this fuel was used in equipment at the Rifle Station."

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REFINERY TREATING PLANT OPERATIONS TREATING PLANT RUNS NO 22, 23, 24

"Light naphtha treating run No. 22, made April 8,1952, and  heavy naphtha treating runs Nos. 23 and 24, made April 28 to 30, are Covered in this report. In run No. 22 light naphtha, produced in cracking plant run No. 45 by recycle cracking a coker distillate,. was caustic washed and  redistilled to produce a stock satisfactory for blending into finished gasoline. The treated light naphtha gum content was satisfactory when produced, but gums formed rapidly during storage and made a second redistillation  necessary before the product could be used. Run No .. 23 charged the heavy naphtha corresponding to the light  naphtha of run No. 22. Treatment consisted of tar-acid and tar-base removal, followed by concentrated sulfuric acid treatment or 18.2 lb. acid per barrel at 20 F.  In run No. 24, heavy naphtha from cracking plant run No. 48, recycle cracking the gas oil from cracked residuum, was treated in a similar manner except that 27 Ibs. of acid per barrel were used. Redistillation of the heavy naphtha's gave products that were satisfactory; these were blended into finished gasoline that was used  in station automotive equipment."

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REFINERY TREATING PLANT OPERATIONS INTERIM REPORT APRIL THROUGH JUNE 1950

"This report covers treating plant runs No. 5 and 6; both of which were cold sulfuric acid treatment of gasoline  produced by thermal cracking of heavy gas oil derived from coking N-T-U crude shale oil. The gasoline stocks charged to these two runs were made during cracking plant runs No. 15 and 16 respectively, and were similar in most respects. A new operational technique was employed for these treating operations with improved results being obtained. The runs were carried out using two different concentrated acid rates and two different  temperatures. characteristics of the treated gasoline are generally as good as those of earlier treated stocks. Sulfur content and lead susceptibility were better than previously attained."

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REFINERY CRACKING OPERATIONS CRACKING PLANT RUN NO. 39

"Run No. 39, which was made between September 19 and 21, 1951, was a recycle cracking operation using visbroken crude N-T-U shale oil as charge stock. It was the first run in which a visbroken crude was cracked thermally under approximately the same operating conditions as those which have been employed with N-T-U crude. It was planned as a means of studying the behavior of the visbroken crude under relatively severe cracking conditions and of determining the yields and product properties that might be obtained. Thee charge stock used in run No. 39 was produced in viscosity  breaking run No. 38 1/2 Run No. 39 was carried out without difficulty. The liquid products were 260 F end point light naphtha, heavy naphtha, and residuum. Coke amounting to about 3 weight percent of the charge accumulated in the reaction chamber, and there was sane loss of light naphtha to the atmosphere and to the product gas, These losses plus some uncertainty about the rate of coke deposition prevent exact determination  of liquid product yields. However, it is apparent that total  naphtha yields were only slightly less than or even equal to those obtained by recycle cracking of N-T-U crude."

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REFINERY CRACKING OPERATIONS REFORMING RUN NO. 27 AND RECYCLE CRACKING RUN NO. 28

"During the period covered by this report (February 1 through March 6, 1951) two cracking plant runs were made. The first of these, run No. 27, was a reforming operation. The second, No. 28, was a recycle cracking run in which both Gas-Combustion and Gas-Flow crude shale oils were used as charge stock. Run No. 27 was the first investigation made at Rifle of reforming  conditions applied to shale oil naphtha. It was strictly exploratory. Bench-scale data obtained at the Laramie Station provided the only guide for the choice of initial operating conditions. The run was not successful from an operating standpoint. Coke deposition in the heater tubes  and in supplementary equipment caused premature shutdowns in both test periods, The information gathered in this run will be of considerable assistance, however, in planning operating procedures for future tests of this type.  Run No. 28 was made to study the recycle cracking of Gas Combustion and Gas-Flow crude shale oils. Both crudes were subjected to the same conditions of pressure and temperature as had been applied to N-T-U crude in run No. 26. This run was conducted without difficulty.  It demonstrated that, under given operating conditions, the liquid product yields from Gas-Flow crude are slightly lower than those obtained with Gas-Combustion and N-T-U oils. It also showed that the characteristics of the individual products from all three crudes are very similar under like conditions of temperature, time, and pressure."

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REFINERY CRACKING OPRATIONS VISCOSITY BREAKING RUN CO 38

"Viscosity breaking run No. 38 was conducted over a period of 84 hours, beg1nn1ng on September 10, 1951. The primary purpose of this run was to produce a fairly large quantity of visbroken crude oil for use as charge  stock in subsequent cracking operations. Secondary purposes were (a) to observe the effects of the operating conditions chosen, and (b) to study the characteristics of the combined liquid product produced   Run No. 38 was a once-through operation using crude N-T-U shale oil as charge stock with a heater outlet temperature of 92Sf. and a pressure of 200 p.s.i.g. The absorber was used to insure the best possible total liquid  recovery. The desired quantity of combined liquid product was produced in the run. This material had Saybolt Universal viscosity at l130 F. of 111 seconds and. a Conradson carbon of 6.5 weight percent. The pour point was around 15 F. It was observed that ''idle variations in pour point could be obtained on identical samples and that the pour point appeared to increase with the age of the sample. No particular operational difficulties were encountered in the run. Some coke deposition occurred in the heater, however, and the heater inlet pressure increased gradually over the entire period of the run."

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REFINERY CRACKING PLANT OPERATIONS RUNS NO 55, 55A, AN 55B

"Suspensoid cracking runs Nos. 55, 55A, and 55B, November 7 to December 1, 1952, were a continuation of the study or this process as applied to mixtures at shale napthas and gas oils. The first two runs were accompanied by operating difficulties and gave little useful  information on yields or products characteristics. They served to point out changes in equipment and operating procedure that would permit the longer on-stream time achieved in run No. 55B. No gains in octane number or naphtha yield over those obtained by conventional thermal cracking were achieved in run No. 55B. The run  demonstrated, however, that operation at higher  temperatures without difficulty with coke deposition is possible. With the aid of this information, runs may be planned which should give definite information on octane improvement and naphtha yield and which will permit evaluation of the Suspensoid process and comparison with standard thermal cracking procedures."

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REFINERY CRACKING OPERATIONS CRACKING PLANT RUN NO. 3

"This run, recycle cracking coker gas oil, was made during the period of June 18 to June 22 to study combined crude shale oil coking and recycle cracking coker gas oil as a means of producing gasoline from shale  oil. The operation was designed tor five test periods with heater outlet temperatures ranging from 960 to lOOOF. Heater outlet pressure was maintained  at 250 p.s.i.g. throughout. The reaction chamber was not used.  Under these conditions, the operation was satisfactory and without excessive coke deposition.  Selected data from coking run No. 21 are included so over-all yields from crude shale oil can be shown. These yields as well as product properties are compared with those obtained from run No, 26 on recycle cracking crude shale oil. A comparison also is made between the results  from this gas oil cracking run and one made at identical conditions on crude;  a higher yield was obtained from the crude but product properties were similar."

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REFINERY CRACKING OPERATIONS RECYCLE RUNS NO. 22 THROUGH NO. 26

"This report covers five recycle cracking runs made to investigate further the yields and quality of products obtained from this type of operation. These were the first runs of this type since the preliminary investigations  in runs Nos. 3, 4, and 5. The results obtained compare favorably with previous data, but additional runs will be necessary to complete the data on this type of operation."

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Thermal Rearrangements of Vinyl Dihydrofurans and Related Isomeric Systems

The first rearrangement of the 2,3-hidydrofuran system was detected by Wilson in 1945 in the course of a routine investigation of tetrahydrofuran derivatives. When tetrahydrofuroamide was dehydrated in the vapor phase it was noted that tetrahydrofuronitrile was accompanied by a small amount of 2,3-dihydrofuran. Moreover, when 1 was pyrolyzed above 400 degrees, formyl cyclopropane appeared in the reaction products along with 2,3-dihydrofuran.

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Utilization of Nahcolite in a Dry SO2-Nox Absorber System

The principal aim of this program was to evaluate chemical factors that affect the efficiency of sulfur dioxide uptake by nahcolite. Among the factors investigated were nahcolite particle size, carrier gas composition and reaction temperature. Following initial work leading to development of methods for identification and chemical analysis of reaction products, a reactor system was designed and constructed. The system was developed to simulate the reaction of sulfur dioxide with a layer of nahcolite on the surface of a bag house filter. The next section of this report describes the major results accomplished with this reaction system and is written in the form of a publication. Following sections describe the results obtained on the analysis of the reactor effluent gas for sulfur dioxide, the effect of nahcolite particle size on sulfur dioxide uptake, the effect of fly ash on nahcolite uptake of sulfur dioxide and the reaction of nahcolite with nitrogen oxides.

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NITROGEN COMPOUND DISTRIBUTION IN SHALE OIL:  COMPARISON OF BENCH-SCALE AND COMMERCIAL-SCALE HYDROPROCESSING

A comparison of the nitrogen distributions in two hydrotreated whole shale oils, one from a bench scale hydroprocess and the other from a commercial scale hydroprocess, is presented. The characterization data are interpreted in terms of hydrodenitrogenation processes. The distribution of nitrogen base types in hydrotreated shale oil was seemingly independent of the conditions and scale of hydroprocessing. However, the distribution of nitrogen compound types in each base type that survive hydrodenitrogenation does depend upon the hydroprocessing conditions. The distribution of nitrogen compound types in a hydrotreated whole shale oil produced by a single pass, bench scale hydroprocess is distinctively different from that in a whole oil produced by a commercial scale hydroprocess which recycled the bottoms with the raw feed. Nitrogen compounds resistant to hydrodenitrogenation apparently build up in the recycled bottoms. Better knowledge of the nitrogen type redistribution occurring during upgrading could enable the process engineer to optimize hydroprocessing conditions to remove nitrogen compounds more effectively.

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ROLE OF SPENT SHALE IN OIL SHALE PROCESSING AND THE MANAGEMENT OF ENVIRONMENTAL RESIDUES (QUARTERLY REPORTS)

On September 1, 1976, work was initiated on a contract on the role of spent shale in oil shale processing. The proposed study was divided into three major tasks: leaching of spent shale, the development of methods to treat water produced during retorting, and an investigation into the sorption properties of spent shale. Each of these major tasks were subsequently divided into projects designed to achieve the overall task. The task, leaching of spent shale, was divided into two projects: retorting of oil shale to produce spent shale samples and equilibrium studies to determine the quantity of leachate that will be removed from the spent shale after a long period of time. The water treatment task was divided into three projects: equilibrium studies dealing with the adsorption of organic contaminants identified in the retort water on selected materials, equilibrium studies of the uptake of ions on selected ion exchange resins, and a project to desorb ammonium carbonate from the retort water with hot gases.

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Coagulation of Oil Shale Retort Waters with Spent Shale and Metal Salts

Oil shale is seen as a potential replacement for our rapidly declining petroleum reserves. Oil shale is neither "oil" nor "shale," but is rather a solid organic material tied up in a marle, a form of limestone or siltstone. An oil is produced by retorting the shale to volatize the oil. Shale is either retorted in situ or mined and retorted above ground. Water is produced during retorting and liberated from the shale and as a product of combustion. In situ retort water production can be considerably increased by groundwater inflow.

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