bluuebunny/crossref_metadata_2025 huggingface dataset:
Adaptation of Congo Red Agar Method and Microtiter Plate Assay to Study Biofilm Formation in Streptomyces
Authors: othmany Rabha EL , Zahir Hafida , Zanane Chorouk , Mazigh Doha , Ellouali Mostafa , Latrache Hassan
Published: May 2021

Streptomyces has many advantages for exploration in biotechnological applications because of their ability to elaborate a multitude of bioactive molecules and secondary metabolites. Despite the importance of this genus in biotechnology, biofilm formation in Streptomyces is under-investigated. The objective of this research is to adapt two assays for the assessment of biofilm formation in Streptomyces. In the present investigation, we assess and follow biofilm formation in eight Streptomyces strains using quantitative and qualitative methods. The quantitative study based on a staining of the retained biomass in the microtiter plate with crystal violet “5%” and destaining using ethanol/acetone mixture, the concentration of crystal violet in the alcoholic solution reflect the intensity of the attached biofilm. On the other hand, the qualitative one consists of using modified freeman’s method a modified congo red agar method based on the color of colonies.

Quantification of biomass by crystal violet staining method confirmed that Streptomyces bellus A43 and Streptomyces bellus A61 are biofilm-forming and this ability increase with the period of incubation. Our results showed that sixStreptomyces strains arenon-slime producing/non-biofilm forming. Two Streptomyces strains are slime producing/biofilm forming; this character vanishes at five days. Further research on genes responsible for biofilm formation in Streptomyces is highly recommended for better understanding of the phenomenon.
Carbon and Nitrogen Sources Effect on Pectinase Synthesis by Aspergillus niger Under Submerged Fermentation
Authors: Begum Gousiya , Munjam Srinivas
Published: May 2021

Pectinases are the commercial enzymes that are abundantly employed in various industries like fruit juice industries for clarification, wine indutsry and paper industry for bleaching up pulp. The present work was done on culture conditions optimization for production of pectinases under submerged fermentation using wheat bran as a substrate. Fungal strains were isolated from vegetable waste dump yard soils of Warangal district of Telangana state and screened for their activity on pectin agar medium. Among 30 isolates, two fungal strains showed good activity and identified them as A. niger and A. flavus. The effects of the different carbon and nitrogen sources on pectinases viz. exo-PG, endo-PG, endo-PL and PME by A. niger with 1% wheat bran was carried out in submerged fermentation. These studies revealed that carbon and nitrogen sources have shown considerable influence on enzyme production. Among all the carbon sources tried, sucrose at 1% was shown to be efficient carbon source for all four types of pectinases under investigation. For endo-PG, endo-PL and PME maximum enzyme production were recorded on 8th day of incubation period but for exo-PG enhanced production was observed on 12th day. A. niger could not produce PME on 12th day from 2.50% to subsequent concentrations. Among nine different nitrogen sources were screened, maximum pectinase production was recorded in sodium nitrate at 0.2 % for A. niger. Endo-PG, endo-PL and PME maximum production were recorded on 8th day of incubation and for exo-PG maximum production was observed on 12th day. No PME production was observed in A. niger on 12th day.
H. Brentwood Oil and Gas Field, Contra Costa County, California
Authors: Ditzler Clark C. , Vaughan Richard H.
Published: May 2021

Brentwood oil and gas field in Contra Costa County is California's northernmost commercial oil-producing area. It is about 40 mi east of San Francisco and 10 mi south of the Rio Vista gas field. The field was discovered in June 1962 by Shell, Occidental, and Brazos' joint well, Heidorn 4-4. The area was developed as a gas field until the discovery of oil in the Ginochio 2-16 well in December 1962. By December 1965, there were 50 producing wells in Brentwood field. Of these, 15 produced predominantly gas with small quantities of associated oil. The other 35 wells produced oil and gas at different ratios.

The Paleocene and Cretaceous reservoir beds dip north at a low angle and are truncated by a south-dipping unconformity surface, which is overlain by a widespread “Meganos gorge” shale unit that provides the major updip trap of the oil and gas pools. The field is traversed by a series of northwest-striking normal faults. The oil-producing portion of the Brentwood field consists of three producing zones in massive sandstone beds separated by shale bodies. These are the First Massive Martinez sand of Paleocene age, the Second Massive Martinez sand of Paleocene age, and the Third Massive Martinez sand of Late Cretaceous C- and D-l-Zone ages. The oil is in 25-100-ft columns over- lain by gas caps ranging upward to 250 ft in thickness. Thinly bedded Upper Martinez sandstone stringers, known as the “Heidorn” and “Ginochio” sands, are about 500-800 ft above the First Massive Martinez and produce essentially dry gas with only minor quantities of condensate.

Recent production from the field has been approximately 2,000 bbls of oil and 10 million cu ft of gas a day. Several gas wells that are completed in gas caps underlain by oil columns have been shut in to conserve reservoir energy. The quality of the gas produced from Brentwood field is exceptionally high for the Sacramento Valley. The Btu values range from 1,050 to more than 1,200.

Gas from the field is delivered by Shell-Dow pipeline to the Dow Chemical Company plant at Pittsburg, California, and the Shell Oil Company refinery at Martinez, California. By the end of 1965, the field had produced approximately 2,300,000 bbls of oil and 13,000 million cu ft of gas.
Introduction to Regional Geology and Typical Gas Fields of Western Anadarko Basin
Authors: Totten Robert B. , Horn Paul H.
Published: May 2021

The Texas and Oklahoma Panhandle areas encompass a vast area of stratigraphic and structural entrapment for gas and oil, principally gas. Significant reserves and production have been found continuously since 1918 and there should be no decrease in activity in the foreseeable future. The Anadarko basin, defined on the south by the buried Amarillo mountains and on the west by the Cimarron uplift, and rising into the shallow Hugoton embayment on the north, received a flood of sediments in the Pennsylvanian which provided the principal reservoir rocks. Morrow, Virgil, and Missouri rocks are the most important producing units.
Hugoton Panhandle Field, Kansas, Oklahoma and Texas
Authors: Mason John W.
Published: May 2021

The Hugoton-Panhandle gas field, in parts of Kansas, Texas, and Oklahoma, is an area of almost 8,500 sq mi and contains one of the world's largest known gas reserves. The field was discovered in 1918 by drilling on a surface structural feature and now includes almost 5.5 million acres which are being drained by 10,500 wells. Production is found in Permian and Pennsylvanian granite wash and carbonate rocks in the south and in Permian dolomite and limestone in the north. The primary controlling mechanisms for the accumulations are, in the south, a compaction anticline over the buried Amarillo ridge and, in the north, a hydrodynamic trap caused by a slight reduction in permeability at the western (updip) edge of the field. In the Kansas part production is limited both updip and downdip by water. The field is a volumetric reservoir and has produced a total of 24.5 trillion cu ft of gas. It now is producing at the rate of 1.4 trillion cu ft a year. Remaining reserve is estimated to be about 28 trillion cu ft.
C. Hardtner Field, Barber County, Kansas
Authors: Young Robert T.
Published: May 2021

The Hardtner field, in south-central Barber County, Kansas, was discovered in 1954. Two zones are productive, the “Conglomerate Sand” (Pennsylvanian) and the Mississippian “Chat.” Trapping is stratigraphic. Cumulative gas production at the end of 1963 was about 75 billion cu ft, and remaining reserves were 75 billion cu ft.
E. Glick Field, Kiowa and Comanche Counties, Kansas
Authors: Euwer Robert M.
Published: May 2021

The Glick field, in Kiowa and Comanche Counties, Kansas, produces from the Mississippian (Osage) “Chert.” The gas is trapped stratigraphically. Cumulative production to January 1, 1967, was 180,280 bbls of 60°-gravity condensate and 80.65 billion cu ft of gas.
Kinta Gas Field, Haskell County, Oklahoma
Authors: Woncik John
Published: May 2021

The Kinta gas field comprises the former Cartersville, McCurtain, Lewisville, West Milton, Lequire, and Kinta gas fields. It is in Haskell County in the northern shelf area of the Arkoma basin. There are approximately 200 gas wells with a total reserve of more than 1 trillion cu ft of gas. Production is from the Spiro Sand (200 wells) of early Atokan age and from the Cromwell Sand (34 wells) of Morrowan age. Production first was established in 1916 from the Hartshorne Sandstone. This reservoir has been depleted. Key discoveries in the deeper Spiro and Cromwell were made by Superior Oil Company in 1951 at Kinta and by Red Bank Oil Company at Cartersville in 1930.

Anticlinal structure is shown in surface and subsurface strata, but the accumulation appears to be controlled stratigraphically by porosity of both the Spiro and Cromwell Sands. Porosity is the result of erratic sandstone deposition and is independent of structure. The area is cut by normal “growth” faults which show greater deposition of Atoka shale in the downt'hrown blocks. Water sands are present in the Spiro and Cromwell north of the Mulberry fault in Haskell County, and south of the fault gas generally is found where these sandstone units are porous.
Natural Gas In Illinois Basin
Authors: Bond D. C. , Bell A. H. , Meents W. F.
Published: May 2021

Most of the natural gas produced in the Illinois basin has been solution gas, produced from oil wells as casinghead gas. Much of this solution gas was flared, especially in the early years of some of the larger fields. In more recent years most of it has been used in producing operations on or near the leases where it is produced.

Gas also has been produced from gas caps over oil reservoirs, and from gas reservoirs not associated with oil. Most of the marketed gas in the Illinois basin has come from such reservoirs. The reservoirs were generally small. Some have contained as much as a few billion cubic feet of gas, and only Midland, in western Kentucky, contained more than 100 billion cu ft.
Oil and Gas in Southwestern Ontario
Authors: Sanford B. V.
Published: May 2021

Southwestern Ontario, an area of about 40,000 sq mi, is underlain by marine sedimentary rocks with a maximum thickness of about 5,000 ft. All geologic systems from Cambrian to Mis- sissippian are represented. Both oil and gas have been produced commercially for more than a century; current production is about 1.3 million bbls of oil and 15 million cu ft of gas annually. Production is from 12 stratigraphic zones from the Cambrian through Devonian Systems. Most of the oil produced has been from shallow Devonian strata; gas has been mainly from reservoirs of Silurian age. In recent years, however, more attention has been directed to the prospects of the deeper Ordovician and Cambrian rocks, and about 28 per cent of the oil now produced is from these strata.
Stony Creek Gas and Oil Field, New Brunswick
Authors: Howie R. D.
Published: May 2021

The Stony Creek gas and oil field, about 9 mi south of Moncton, New Brunswick, is the only productive field in Canada east of the province of Ontario. Production is from deltaic sandstone beds in the Albert Formation of Mississippian age. The field has an area of only 1,830 acres and is on the gently dipping north limb of the Weldon syncline.
Use of Natural Gas and Natural-Gas Products in the Manufacture of Petrochemicals
Authors: Bunn George P.
Published: May 2021

The manufacture of petrochemicals, now a growing industry, is destined to become even more important economically. Natural gas, already the predominant source of raw material for petrochemicals because of several advantageous factors, will become an even more important source. Petrochemical fertilizers, plastics, detergents, textiles, and rubbers, in particular, yield a substantial part of the industry's income of more than $5 billion annually. The popular reception of petrochemicals, many of which are equal or superior replacements for natural products, has stimulated research from which phenomenal results promise the appearance of many new products,
Sulfur—its Occurrence, Production, and Economics
Authors: Myers John C.
Published: May 2021

Sulfur is produced as elemental sulfur from the cap rock overlying salt domes; from sedimentary and volcanic deposits; and from hydrogen sulfide in sour-gas and sour-oil fields. It is produced as sulfur compounds from pyrite, pyrrhotite, and marcasite ores and as sulfur dioxide gas in the smelting of sulfide ores.

Salt domes are present in Texas and Louisiana along the north shore of the Gulf of Mexico, and on the Isthmus of Tehuantepec along the south shore of the Gulf of Mexico. The recovered sulfur—also classed as elemental—is produced with gas along the Foothills belt at the eastern edge of the Rocky Mountains, from the northern part of Canada southward to and including the Permian basin of Texas and New Mexico; along the south side of the Ouachita folded belt of Texas, Arkansas, and Mississippi; and on the eastern side of the Pyrenees Mountains in southern France. Many sedimentary deposits are found on several continents and iron sulfide ores also are found in numerous places.

Sulfide has more than 70 uses in industry, but the greatest is in the manufacture of sulfuric acid. The production from sources containing elemental sulfur is nearly equal to the production from sulfur compounds. In 1963, demand for sulfur had approached the capacity to produce; the demand should increase more rapidly than production and the finding of new deposits, unless an increase in price stimulates exploration and resultant discovery of new sources or revival of old ones.
Factors in Exploration for Nonassociated Natural Gas
Authors: Conselman Frank B.
Published: May 2021

Natural gas now is being sought independently of petroleum because of current market conditions. It is therefore appropriate to review exploration methods to determine the need for specialized gas-finding techniques.

Associated gas reserves will continue to share in the results of oil and gas exploration and development. However, nonassociated reserves, which either have never been associated with oil or have become dissociated from oil, appear to justify specific study.

Natural gas may originate entirely apart from oil. Significant data concerning both the origin and behavior of methane—the principal constituent of gas—are available from coal mines and from metal mines cutting carboniferous sediments.

Gases originating concurrently with crude oil may separate because of important physical and chemical differences between the two fluids. Migration need not be over long distances; there are many examples of commercial gas fields caused by short-range segregation.

New field discoveries in unlikely reservoirs, restudy of the old carbon-ratio idea, and information obtained from the formation of artificial gas caps by underground storage suggest that gas-finding may involve more than normal oil-finding criteria. New definitions may be needed of what is a source rock and what is a reservoir. Ideas of prospective territory and methods of prospecting can stand review. Techniques for detection and recognition of gas reserves when drilled need improvement. There is adequate gas in the ground awaiting discovery to take care of the needs for the near future, if the political and economic situation provides an incentive to find it.
Origin and Accumulation of Natural Gas
Authors: Haun John D. , Lucas George B.
Published: May 2021

This paper is intended to introduce the student or nongeologist to some of the concepts of the origin and accumulation of natural gas. Natural gases consist of methane, carbon dioxide, and nitrogen, and small quantities of hydrogen sulfide, heavier hydrocarbons, helium, and, very rarely, hydrogen. It appears most probable from geochemical considerations that the major gases result from bacterial action on organic and inorganic matter within the sedimentary rocks of the earth's crust. Thermal processes may account for some of the gases, notably methane and carbon dioxide, in special cases. The inert gas, helium, is unique in that it is the product of radioactive decay of uranium and thorium which are present in trace quantities in most rocks and sediments.

Migration of gases from source beds to reservoir rocks is a result of both solution in ground waters, with subsequent release as pressure decreases, and migration as gas through the saturated waters within porous rocks. Entrapment and accumulation occur where the rising gases meet strata impermeable to gas.
C. Homeglen-Rimbey Field, Alberta
Authors: Webb J. B. , White R. J.
Published: May 2021

The Homeglen-Rimbey field is in Tps. 42-43, Rs. 1-2, W. 5M., west-central Alberta, Canada. It is the southernmost in the chain of gas and oil fields extending south-southwest from Leduc field, all of which have large accumulations of gas and/or oil in the Leduc (D-3) formation, the well-known reef unit of the Upper Devonian.

The surface rocks in this area comprise sandstone and shale of Paleocene age which occupy the deeper part of the Alberta syneline. The strata have a regional southwestward dip of about 50 ft/mi. The subsurface section includes freshwater and marine Upper and Lower Cretaceous strata separated from Mississippian and Devonian limestone, dolomite, and shale by a pronounced regional unconformity. The top of the Upper Devonian Leduc reef formation is 7,500-7,700 ft deep, and the base of the accumulation (oil/water contact) at about 8,000 ft. The maximum thickness of gas pay found is 552 ft and the underlying oil column is about 26 ft thick. The field is approximately 12 mi long and generally 2 mi wide, and contains a major wet-gas reserve.
Rational Analysis of Future Rate of Natural Gas Production
Authors: Elliott Martin A. , Von Fredersdorff C. G.
Published: May 2021

An analysis of 1945-1957 gas-production statistics gave a quantitative correlation between cumulated production, P, and cumulated discoveries, D, of the form P = KDn, where K and n are constants. The recent trend of life index, L, with time, t, was represented adequately by the equation of a hyperbola, (L — A)(t — to + t8) = C, where to is a base year, A is a life-index asymptote, and t8 and C are constants. Combination of these correlations with the definition of the rate of gas production, rp = R/L, where R is proved reserves, formulates mathematical equations which closely fit the past yearly production data. This approach can be extended for computing future production rates mathematically. One significant result is the prediction of 1,500 trillion cu ft ultimate discoveries, for which the produc- tion-rate forecast, under conditions of a 15-yr life-index asymptote, shows a 16.4 trillion cu ft a year peak in 1980. Calculated effects on the rate forecasts can be explored over an illustrative 1,500-2,500 trillion cu ft range of ultimate discoveries, and 0-, 15-, and 20-yr life-index asymptotes.
Natural Gas Resources of the United States
Authors: Beebe B. W. , Hanley John M.
Published: May 2021

Natural gas requirements in the United States increased from 4 trillion cu ft in 1946 to 16.0 trillion in 1965. Projected demand calls for more than 25 trillion cu ft in 1980—1.5 times the consumption in 1965. The nation will have consumed 320 trillion cu ft of natural gas by 1980; this exceeds the estimated proved recoverable reserves at the end of 1965 by more than 30 trillion cu ft.

Potential supplies consist of estimated recoverable reserves replenished by new discoveries, extensions, and revisions; at the end of 1965, proved recoverable reserves in the United States were estimated to be 286.5 trillion cu ft.

Trends in reserve/production (R/P) ratio—estimated recoverable reserves divided by production for a given year—are important; a continuing downward trend indicates the industry can not meet demand because of decline in peak productivity. A declining trend can be decelerated or reversed provided that there is natural gas to be found, there is adequate incentive to find it, and technology permits its discovery, development, and production.

Total future potential supply consists of estimated proved recoverable reserves and undiscovered future supplies. Undiscovered potential supplies consist of several categories of increasing uncertainty (1) development of known deposits—lateral or vertical extensions, and revisions of estimates; (2) new discoveries in geologic provinces and formations, and types of traps already proved productive; (3) in geologic provinces known to be productive, but in remote areas, in new types of accumulation, and/or in formations not known previously to be productive in that area; and (4) the most speculative may be found in provinces or basins which have not yielded gas previously.

The estimation of undiscovered potential future supply at any particular time is strictly a problem in geology and reservoir engineering. Natural gas is found in rocks and not in mathematical curves, formulae, or economic theory. Most estimates extant have been based on questionable methods and have used obsolete and conflicting data.

How should the potential future supply of natural gas be forecast? There are two fundamental factors on which to rely—thorough knowledge of the relationship of natural gas to the detailed geology of each area examined, and experience.

The Supply Division of the Future Gas Requirements and Supply Comm. of North America is composed of nearly 100 skilled, experienced geologists and engineers, each assigned to study and analyze a local area of which he is completely knowledgeable.

Useful estimates of undiscovered potential future supply, like those of proved reserves, are dynamic and must be reviewed frequently in light of changing conditions. The Committee is satisfied that an adequate supply of natural gas can be made available continuously within the foreseeable future provided that there is adequate incentive coupled with technological progress.
Occurrence of Natural Gas in Cenozoic Rocks in California
Authors: Crawford F. D.
Published: May 2021

A total of 675 billion cu ft of natural gas was produced in California during 1964, approximately 57 per cent of which was wet gas from 182 fields in all of the major oil-producing basins of the state; 43 per cent was dry gas from 93 fields, primarily in the Sacramento and northern San Joaquin Valleys (Fig. 1). Accumulations are found in a variety of structural and stratigraphic traps. Cumulative production to the end of 1964 was 20.7 trillion cu ft, four-fifths of which was wet gas. Reserves were estimated at approximately 10 trillion cu ft.

Outstanding among the state's gas fields are Kettleman Hills, in the San Joaquin Valley, with a cumulative production of 2.59 trillion cu ft of wet gas; and Rio Vista, a dry gas field in the Sacramento Valley, which has produced 2.26 trillion cu ft. Other fields with cumulative production exceeding 1 trillion cu ft are Ventura in the Ventura basin and Long Beach in the Los Angeles basin.
C. Introduction to Geology of Gas Occurrence in Sacramento Valley
Authors: Reedy R. D.
Published: May 2021

Bounded by the Sierra Nevada on the east, the Coast Range on the west, the large northeast- trending Stockton fault on the south and the Klamath Mountains on the north, the Sacramento Valley provides a unique natural laboratory for locating natural gas reserves. The current total reserve estimate for the valley is more than 7 trillion cu ft, a figure which is being revised upward constantly because of the high success ratio of drilling operations. Dry gas is found in rocks of Pliocene, Eocene, and Late Cretaceous ages, which constitute a maximum stratigraphic thickness of more than 50,000 ft near the south-central valley or Rio Vista portion of the basin.

The mode of entrapment of gas is extremely varied within the valley; however, it is generally true that most purely structural traps are in the southern Rio Vista part of the basin. Faulting and domal closure within this thick Eocene blanket-type sequence have trapped nearly two- thirds of -the known reserves. Northward in the “Colusa sub-basin,” trapping is more complex because of extreme irregularity in Upper Cretaceous F Zone sandstone distribution. This stratigraphic unit and associated minor structural features liave been the target of much exploratory activity in the past. Recent exploratory activity has been directed toward deeper drilling in search of Cretaceous accumulations in the Rio Vista part of the basin.
B. Natural Gas in Eel River Basin, Humboldt County, California
Authors: Ogle Burdette A.
Published: May 2021

California's northernmost large onshore part of the offshore Pacific Coast Tertiary basin is the Eel River basin. The main part of the basin, in the Eel River Valley area, contains approximately 12,000 ft of Tertiary and Quaternary sedimentary rock ranging in age from late Miocene to late Pleistocene and Recent. Folding and thrust faulting in mid-Pleistocene time formed the present major structure of the basin, the Eel River syncline, with anticlinal folds on the north and south limbs and thrust faults on the northeast and east. Later warping along these structural axes continues; many of the structures can be defined by topographical expression. Upper Pliocene sandstone (Rio Dell Formation of the Wildcat Group) is productive in two fields, Tompkins Hill, discovered in 1937, and Table Bluff, discovered in 1960. Gas also has been found in lower Pliocene sandstone (Eel River Formation of the Wildcat Group) at Grizzly Bluff. Gas is trapped in an anticlinal fold at Tompkins Hill, but part of the trapping is stratigraphic. At Table Bluff, lenticular sandstone bodies form stratigraphic traps on an anticline with uncertain westerly closure. Trapping at Grizzly Bluff is not completely understood; it is probably stratigraphic on a,n anticlinal fold.
North Park, Colorado—An Oil and Gas Province
Authors: Oburn Richard C.
Published: May 2021

North Park is the northernmost of two topographic basins that constitute a single intermontane structural basin in north-central Colorado. Petroleum exploration began there in 1912 with a test of one of the many folds apparent at the surface in the area. To date four commercial oil and gas fields have been developed in the northeast quadrant of the park. The predominant structural trend is west of north and is the result of a couple produced during Laramide orogeny. Later deformation in the late Miocene or early Pliocene was a result of north-south-oriented stresses. The first recorded deposition in North Park began in the Late Permian. This sedimentation was the beginning of a long sequence of marine and epicontinental deposition. Several excellent pay zones are found in the Mesozoic beds, especially those of Early Cretaceous age. Future discoveries in this small but petroliferous basin depend upon more detailed structural and stratigraphic studies.
Principles of Gas Occurrence, San Juan Basin
Authors: Silver Caswell
Published: May 2021

Gas in the San Juan basin is present over a large area which, in gross, occupies a structural basin but has a homoclinal position with respect to individual sandstone lenses. The fluids of the principal Cretaceous producing units of the San Juan basin are now in a dynamic state, with flow from areas of higher outcrop to lower outcrop. The potentiometric surface of each principal gas-producing zone contains a potentiometric sink coincident with the oil and gas accumulations. The sinks are difficult to explain, but appear to result from the prior presence of oil and gas accumulations whose volume and pressure have been modified by leakage. This mechanism may be the fundamental geologic explanation for pressure sinks in potentiometric surfaces elsewhere.

There is no clear stratigraphic record of the former presence of sedimentary rocks younger than the San Jose Formation of Eocene age in the area of the gas deposits. Gas accumulation, if related to compaction, must therefore have occurred before late Eocene time, and the development of dynamic conditions of fluid flow similar to the present pattern must have begun in or after the late Eocene. The structural positions of the gas deposits are not indicative of accumulation under hydrodynamic conditions. The combined evidence of geologic history, structural position, and salinity indicate normal gravitational accumulation in updip porous wedges or isolated, wholly shale-contained stratigraphic accumulation in discrete lenses under compaction. The writer believes the accumulation of gas predates development of the present basin structure.

The paucity of oil in direct association with the gas and the lack of asphaltic outcrops suggest that the areas and volumes of the original gas accumulations were much larger than those of present deposits, which are only remnants of original accumulations. Although the Pictured Cliffs, Cliff House, Gallup, and Dakota strata have discernible lenticularity which would preserve the gas deposits under present hydrodynamic conditions, there is no such readily discernible stratigraphic control of the largest accumulation of all in the Point Lookout Sandstone.

The nature and gross volume of the San Juan basin gas deposits indicate that under unusual and perfect conditions of source, expulsion, entrapment, and preservation the volume of gas generated by 1 cu mi of source beds can be nearly 5-10 billion cu ft.
Opelika Field, Henderson County, Texas
Authors: Brogdon D. R.
Published: May 2021

The Opelika field, in northeastern Henderson County, was discovered in 1937. The principal producing formation is the Rodessa (Lower Cretaceous). The accumulation is trapped in a faulted domal anticline ; there is minor stratigraphic trapping. Gas-recycling operations were begun in 1941.
Natural Gas in Post-Paleozoic Rocks of Mississippi
Authors: Beebe B. W.
Published: May 2021

The first production of hydrocarbons from post-Paleozoic rocks in Mississippi resulted from the discovery of the Jackson gas field in 1930. Production was from the “Jackson gas rock," a local reef facies, in the upper part of the Selma Group of Late Cretaceous age. The field now is depleted after having produced more than 117 billion cu ft of gas, and is used for gas storage. Since the discovery of the Jackson gas field, nonassociated-gas production has been established from Tertiary Wilcox, Cockfield, and Sparta; Upper and Lower Cretaceous; and Upper Jurassic strata. By far the most important production has been from the Upper Cretaceous sandstones of the Eutaw and Tuscaloosa. Dissolved or associated gas is produced from many oil wells in Mississippi. However, 70-80 per cent of all the gas produced in Mississippi from post-Paleozoic reservoirs in the past 10 years was nonassociated. Many of the nonassociated-gas fields also produce condensate in varied quantities.

In 1964, Mississippi ranked eighth among the states in estimated proved reserves, and ninth in net production of natural gas. Over the past 10 years, Mississippi has shown a net decrease of 88,233 Mcf in estimated proved recoverable reserves.

Most of the known natural gas accumulations in Mississippi are controlled structurally, but this control is modified by changes in character of the producing reservoirs and some accumulations are in combination structural-stratigraphic traps. Most of the known local structural features are the result of salt movement, although shallow salt diapirs have not afforded significant production of either oil or gas in Mississippi. All of the major gas-producing fields in Mississippi are at least 10 years old, and there have been no large significant gas discoveries since Maxie field was found in 1952. The future supply of natural gas in Mississippi, therefore, will depend on success in location of gas- bearing stratigraphic traps and additional structures in the Upper Cretaceous and Tertiary, and on deep exploration of Lower Cretaceous and Jurassic strata. The lowermost Cretaceous and Jurassic have been explored only partially because of depth and high costs of exploration and development. Production has been established from these strata in several wells. Most of the Upper Jurassic gas, particularly from the Smackover, is reported to contain large quantities of hydrogen sulfide and inert gases.
Natural Gas in North Dakota
Authors: Anderson Sidney B. , Eastwood William P.
Published: May 2021

Almost all natural gas produced in North Dakota is casinghead gas from oil pools in the Madison Group along the Nesson anticline and from pools in Burke County. Relatively minor quantities of dry gas are produced from the gas fields of the North Dakota part of the Cedar Creek anticline. Only the natural gas from these areas is used commercially; the casinghead gas from other areas in North Dakota is flared.

There is a large volume of nitrogen gas in the Minnelusa Formation in the central part of the Nesson anticline, and nitrogen is produced with a heavy crude from the Heath Formation pools in the southwestern part of the state.

There are underground storage facilities in the Montana part of the Cedar Creek gas field and storage caverns in salt beds near Williston and Lignite, North Dakota. Gas production in North Dakota is less than demand and gas must be imported.
Worsham Gas Field, Reeves County, Texas
Authors: Winn Vernard
Published: May 2021

The first significant gas discovery from sandstone of the Bell Canyon Formation in the Delaware basin was the Worsham field; prior production from this formation had been predominantly oil. The entrapment in the Worsham field is mainly structural, whereas stratigraphy appears to be the controlling factor in other Bell Canyon fields.
Natural Gas in Texas Part of Marietta Syncline, Cooke and Grayson Counties, Texas
Authors: Barker D.
Published: May 2021

The area of the Marietta syncline in Cooke and Grayson Counties, Texas, appears to have the greatest potential for future gas production in North Texas. Extensive exploration for gas in this area began in 1951, although it long had been important for oil production. Both oil and gas accumulations are controlled mainly by structure.

Solution gas is the main type of gas produced, but production of nonassociated gas is expected to increase. Solution-gas production is mostly from sandstones of Pennsylvanian (Des Moines and Atoka) age. Important gas-distillate reserves have been discovered in the Oil Creek Formation of Ordovician age, and the Ellenburger also yields some gas distillate. The Oil Creek and Ellenburger should receive further exploration. The multiple-pay section in this area is the deepest and thickest in North Texas.
Carter-Knox Gas Field, Oklahoma
Authors: Reedy Harold J.
Published: May 2021

The Carter-Knox gas field is in the southeastern end of the Anadarko basin in southeastern Grady County and northeastern Stephens County, Oklahoma. It produces oil with associated gas from rocks of the Permian System, and from the Hoxbar, Deese, and Springer Groups. A significant gas reserve was discovered in 1956 by deeper drilling which first tested the pre-Pennsylvanian formations. Gas- condensate production is from the Simpson Group, and the Bromide Formation is the most important zone. The Permian strata form an elongate, faulted anticline with shallow dips. The Pennsylvanian strata are eroded deeply beneath the Permian unconformity and form a very steeply dipping, faulted anticline. The pre-Pennsylvanian structure is an anticline parallel with the shallower features but approximately 1 mi west. The Carter-Knox gas field covers an area of approximately 11 sq mi, 1 mi wide and 11 mi long. First full-scale gas deliveries began on December 17, 1959, with approximately 32 million cu ft of gas a day. Gas production previously had been limited to local sales on a temporary contract of 2-10 million cu ft of gas a day. As of January 1, 1960, the Carter-Knox gas field had produced 878,314 bbls of condensate with 6,710,778,000 cu ft of gas.
Multi-tip edge coupler for integration of a distributed feedback semiconductor laser with a thin-film lithium niobate modulator
Authors: Li Lianyan , Ma Yuxin , Zhang Yunshan , Li Simin , Shi Yuechun , Chen Xiangfei
Published: May 2021

Lithium niobate-on-insulator (LNOI) has been emerging as a popular integration platform
for optical communications and microwave photonics. An edge coupler
with high coupling efficiency, wide bandwidth, high fabrication and
misalignment tolerance, as well as a small footprint is essential to
couple light in or out of the LNOI chip. Some edge couplers have been
demonstrated to realize fiber-to-chip coupling in the last few years,
but the coupling with distributed feedback (DFB) semiconductor laser
is rarely studied. In this paper, we propose a multi-tip edge coupler
with three tips to reduce the mode size mismatch between the LNOI
waveguide and the DFB laser. The tilted sidewall, fabrication
tolerance, misalignment tolerance, and facet reflection due to the
effective index mismatch are discussed. It shows that the proposed
multi-tip edge coupler can be practically used in the production of
effective LNOI integrated chips.
The molecular and metabolic program by which white adipocytes adapt to cool physiologic temperatures
Authors: Mori Hiroyuki , Dugan Colleen E. , Nishii Akira , Benchamana Ameena , Li Ziru , Cadenhead Thomas S. , Das Arun K. , Evans Charles R. , Overmyer Katherine A. , Romanelli Steven M. , Peterson Sydney K. , Bagchi Devika P. , Corsa Callie A. , Hardij Julie , Learman Brian S. , El Azzouny Mahmoud , Coon Joshua J. , Inoki Ken , MacDougald Ormond A.
Published: May 2021

Although visceral adipocytes located within the body’s central core are maintained at approximately 37°C, adipocytes within bone marrow, subcutaneous, and dermal depots are found primarily within the peripheral shell and generally exist at cooler temperatures. Responses of brown and beige/brite adipocytes to cold stress are well studied; however, comparatively little is known about mechanisms by which white adipocytes adapt to temperatures below 37°C. Here, we report that adaptation of cultured adipocytes to 31°C, the temperature at which distal marrow adipose tissues and subcutaneous adipose tissues often reside, increases anabolic and catabolic lipid metabolism, and elevates oxygen consumption. Cool adipocytes rely less on glucose and more on pyruvate, glutamine, and, especially, fatty acids as energy sources. Exposure of cultured adipocytes and gluteal white adipose tissue (WAT) to cool temperatures activates a shared program of gene expression. Cool temperatures induce stearoyl-CoA desaturase-1 (SCD1) expression and monounsaturated lipid levels in cultured adipocytes and distal bone marrow adipose tissues (BMATs), and SCD1 activity is required for acquisition of maximal oxygen consumption at 31°C.
Stress, drink, leave: An examination of gender-specific risk factors for mental health problems and attrition among licensed attorneys
Authors: Anker Justin , Krill Patrick R.
Published: May 2021

Rates of mental illness and heavy alcohol use are exceedingly high in the legal profession, while attrition among women has also been a longstanding problem. Work overcommitment, work-family conflict, permissiveness toward alcohol in the workplace, and the likelihood of promotion are all implicated but have yet to be systematically investigated. Data were collected from 2,863 lawyers randomly sampled from the California Lawyers Association and D.C. Bar to address this knowledge gap. Findings indicated that the prevalence and severity of depression, anxiety, stress, and risky/hazardous drinking were significantly higher among women. Further, one-quarter of all women contemplated leaving the profession due to mental health concerns, compared to 17% of men. Logistic models were conducted to identify workplace factors predictive of stress, risky drinking, and contemplating leaving the profession. Overcommitment and permissiveness toward alcohol at work were associated with the highest likelihood of stress and risky drinking (relative to all other predictors) for both men and women. However, women and men differed with respect to predictors of leaving the profession due to stress or mental health. For women, work-family conflict was associated with the highest likelihood of leaving, while overcommitment was the number one predictor of leaving for men. Mental health and gender disparities are significant problems in the legal profession, clearly requiring considerable and sustained attention.
Implicit learning of non-verbal regularities by deaf children with cochlear implants: An investigation with a dynamic temporal prediction task
Authors: Fastelli Ambra , Mento Giovanni , Marshall Chloë Ruth , Arfé Barbara
Published: May 2021

Some deaf children continue to show difficulties in spoken language learning after cochlear implantation. Part of this variability has been attributed to poor implicit learning skills. However, the involvement of other processes (e.g. verbal rehearsal) has been underestimated in studies that show implicit learning deficits in the deaf population. In this study, we investigated the relationship between auditory deprivation and implicit learning of temporal regularities with a novel task specifically designed to limit the load on working memory, the amount of information processing, and the visual-motor integration skills required. Seventeen deaf children with cochlear implants and eighteen typically hearing children aged 5 to 11 years participated. Our results revealed comparable implicit learning skills between the two groups, suggesting that implicit learning might be resilient to a lack of early auditory stimulation. No significant correlation was found between implicit learning and language tasks. However, deaf children’s performance suggests some weaknesses in inhibitory control.
Auditory evoked potentials: Differences by sex, race, and menstrual cycle and correlations with common psychoacoustical tasks
Authors: McFadden Dennis , Champlin Craig A. , Pho Michelle H. , Pasanen Edward G. , Maloney Mindy M. , Leshikar Erin M.
Published: May 2021

Auditory brainstem responses (ABRs) and auditory middle-latency responses (AMLRs) to a click stimulus were measured in about 100 subjects. Of interest were the sex differences in those auditory evoked potentials (AEPs), the correlations between the various AEP measures, and the correlations between the AEP measures and measures of otoacoustic emissions (OAEs) and behavioral performance also measured on the same subjects. Also of interest was how the menstrual cycle affected the various AEP measures. Most ABR measures and several AMLR measures exhibited sex differences, and many of the former were substantial. The sex differences tended to be larger for latency than for amplitude of the waves, and they tended to be larger for a weak click stimulus than for a strong click. The largest sex difference was for Wave-V latency (effect size ~1.2). When subjects were dichotomized into Non-Whites and Whites, the race differences in AEPs were small within sex. However, sex and race interacted so that the sex differences often were larger for the White subjects than for the Non-White subjects, particularly for the latency measures. Contrary to the literature, no AEP measures differed markedly across the menstrual cycle. Correlations between various AEP measures, and between AEP and OAE measures, were small and showed no consistent patterns across sex or race categories. Performance on seven common psychoacoustical tasks was only weakly correlated with individual AEP measures (just as was true for the OAEs also measured on these subjects). AMLR Wave Pa unexpectedly did not show the decrease in latency and increase in amplitude typically observed for AEPs when click level was varied from 40 to 70 dB nHL (normal Hearing Level). For the majority of the measures, the variability of the distribution of scores was greater for the males than for the females.
The influence of the antithymocyte globulin dose on clinical outcomes of patients undergoing kidney retransplantation
Authors: Linhares Kamilla , Taddeo Julia Bernardi , Cristelli Marina Pontello , Proença Henrique , Ficher Klaus Nunes , de Marco Renato , Gerbase-DeLima Maria , Medina-Pestana Jose , Tedesco-Silva Helio
Published: May 2021

Optimizing antithymocyte globulin (rATG) dosage is critical for high immunological risk patients undergoing a repeat kidney transplant. This natural retrospective cohort study compared clinical outcomes of two successive cohorts of consecutive recipients of retransplants receiving 5 x 1 mg/kg (rATG-5, n = 100) or a single 3 mg/kg (rATG-3, n = 110) dose of rATG induction therapy. All patients had negative complement-dependent cytotoxicity crossmatch and no anti-HLA A, B, DR donor-specific antibodies (DSA). The primary endpoint was efficacy failure (first biopsy-proven acute rejection, graft loss, or death) at 12 months. There was no difference in the cumulative incidence of efficacy failure (18.0% vs. 21.8%, HR = 1.22, 95% CI 0.66–2.25), respectively. There were no differences in 3-years freedom from biopsy proven acute rejection, and patient, graft, and death-censored graft survivals. There were no differences in the incidence of surgical complications (25.0% vs. 18.2%; p 0.151), early hospital readmission (27.8% vs. 29.5%; p = 0.877) and CMV infections (49% vs. 40%; p = 0.190). There were also no differences in the incidence (59.6% vs. 58.7%, p = 0.897) and duration of delayed graft function but a stable difference in estimate glomerular filtration rate was observed from month 1 (54.7±28.8 vs. 44.1±25.3 ml/min/1.73 m2, p = 0.005) to month 36 (51.1±27.7 vs. 42.5±24.5, p = 0.019). Mean urinary protein concentration (month 36: 0.38±0.81 vs. 0.70±2.40 g/ml, p = 0.008) and mean chronic glomerular Banff score in for cause biopsies (months 4–36: 0.0±0.0 vs. 0.04±0.26, p = 0.044) were higher in the rATG-3 group. This cohort analysis did not detect differences in the incidence of efficacy failure and in safety outcomes at 12 months among recipients of kidney retransplants without A, B, and DR DSA, receiving induction therapy with a single 3 mg/kg rATG dose or the traditional 5 mg/kg rATG.