Search Documents

By Charles R. Fettke

The outstanding event of the year 1929 in the Appalachian area was the intensive drilling activity in the Bradford and Richburg pools of northwestern Pennsylvania and southwestern New York State, particularly the former, in connection with the continued extension of the five-spot system of water-flooding. More new development work was undertaken and completed than during any previous year since reclamation methods were first applied. This was due in part to an excellent price for oil and in part to discovery of the fact that more intensive methods (five-spotting) yielded greater profit. While several oil wells of comparatively large initial production were completed, no new oil pools of significance were discovered in the Appalachian area during the year. A number of small gas pools were opened in areas already surrounded by producing wells and at least three others in areas located some distance from any producing pools. Petroleum Development According to statistics of the U. S. Bureau of Mines, 33,7,57,000 bbl. of petroleum were produced in the Appalachian field during 1929 as compared to 31,060,000 bbl. in 1928.' Of the total 1929 production, 23,391,618 bbl. consisted of Pennsylvania grade oil as compared to 21,096,710 bbl. in 1928. The 1929 Pennsylvania grade production represents an increase of 37.4 per cent. over that of 1924. This increase can be attributed largely to the rapid development of water-flooding in the Bradford and Richburg pools. The Bradford field of northwestern Pennsylvania and adjaccnt portions of New York State experienced the busiest year since the boom days of the early eighties. Wells completed during the year totaled 2679.2 In spite of the high prices asked for acreagc, which in some of the choicest territory has been as high as $6000 an acre, a considerable number of properties changed ownership during the year. There is at present a pronounced tendency to consolidate the great number of small individually operated properties into larger units.

Jan 1, 1930

By F. E. Poulson

The discovery of two new fields, Van, in East Texas, and Darst Creek, in the Balcones fault zone, is the outstanding development in 1929. The first six months was one of the most inactive periods in the history of East Texas. Five of the interior salt domes, which had been so eagerly sought as a result of the Humble Oil & Refining Co.'s strike on the Boggy Creek dome in 1927, were drilled with discouraging results, and the Boggy Creek field itself had fallen far short of expectations. Kelsey, a structure of considerable magnitude and extent in Upshur County, was equally disappointing; the Amerada Petroleum Corpn.'s initial test on this structure was dry. The situation improved in the latter half of the year. On Oct. 13, 1929, the Pure Oil Co. discovered the Van field. This gained for East Texas a permanent place in point of future potential production. There was a similar reaction in the Balcones fault zone. The Salt Flats (Bruner) field, the important discovery of 1928, proved its rating as a second Luling, but on account of repeated failures to extend the productive zone, wildcatting during the first half of 1929 in the Luling district was dilatory. In July, however, Darst Creek, a third fault-line field of majori mportance producing from Edwards limestone (Lower Cretaceous), was discovered. Retarded as development in this field has been by various attempts at proration, interest in the Balcones fault zone fields centered on Darst Creek as the year 1929 drew to a close. Development in East Texas Fields Discovered during 1929 Van.—The discovery well, Jarman No. 1 of the Pure Oil Co., is near the town of Van in the southeastern part of Van Zandt County, Texas. It is 55 miles northeast of the Powell field in Navarro County and 45 miles west of north from the Boggy Creek field in Cherokee and Anderson counties. Early in 1927, the Van area was submitted to seismographic exploration and outlined as a large anticline, the apex of which seemed to be

Jan 1, 1930

By O. I. Deschon, Ralph Arnold

Deep drilling was the keynote of the more important developments in the North Rocky Mountain region during 1929, with Montana recording the most important achievement through discovery of three new oil fields. Alberta produced 1,000,000 bbl. of 74 gravity naphtha, showing a considerable gain over 1928, developed a commercial oil pool in Turner Valley and extended that field 8 miles southward. Wyoming's discovery field was deepened to a second producing horizon, giving impetus to deeper drilling, and practically every Wyoming oil field will have a deep test either this year or in the near future. Whereas Montana prospecting has been confined to the shallow plains structures, since the discovery of Kevin-Sunburst field, the coming year will see an active search for new oil and gas pools in sharp-dip structures, following the success of prospecting in the Sweetgrass Hills during 1929. A dozen or more structures have been mapped in North Central Montana, several of these straddling the Alberta border. Four structures tested thus far have all shown commercial oil or gas or both. Sweetgrass Hills The first important development in the Hills area was the Rogers-Imperial gasser, which had an initial of 51,000,000 cu. ft. of dry gas per day, with a rock pressure of 1080 lb. This well is located on a sharp nose running north from the hills into Alberta. Several wells drilled by independent operators on the American side, on the west flank of reserve structure, have developed a total open flow capacity of 30,000,000 cubic feet. The third structure tested in the Hills area is known as Bears Den, where commercial oil was found at the base of the Cretaceous at 2470 ft. The existence of oil in three lower sands has been established by two wells on the top of the structure, these two wells finding gas flows of 10,000,000 and 15,000,000 cu. ft., respectively, in the horizon where

Jan 1, 1930

By H. W. Bell

There was considerable prospecting for new supplies of oil in Arkansas during the past year, regardless of the overproduction affecting the industry throughout the country. Justification for this new work was not lacking, as the local markets more than threatened to absorb a declining production. There were, however, no important new discoveries in the state during 1929. The McDonald area in sec. 2515, S.-18 W., threatened to expand into a major producing area. Oil showings had been encountered here in wells drilled by the McDonald Oil Corpn. as early as the fall of 1928. In July, 1929, an initial production of 1000 bbl. of 32" oil was obtained in McDonald Bros. B-3 Wilson, from a sand at 2780 to 2786 ft., which is about 80 ft. higher than the sand previously tested in the neighboring wells. This production declined rapidly. At the end of the year there were six producers making about 200 bbl. per day total. Seven dry holes have temporarily stopped development in that area. The showing of B-3 was sufficient to cause considerable leasing activity. The area lies several miles west of the Louann portion of the Smackover field. The discovery well went to 2873 ft. and found Glen Rose lime in bottom. The age of the producing sand is in doubt; it seems closely related to the Tokio sand. During 1929, several paying wells were brought in, as a northeastern extension to the Smackover Heavy area, in sec. 34 and 35-15-15, from the Nacatoch sand. Over 20 new wells were drilled and resulted in at least 1500 bbl. production. The down-dip or off-structure territory contiguous to the Smackover uplift was further tested at various locations with the usual results; that is, a showing of "salt water gas," which soon blew off and in some cases a slight showing of oil. These gas showings, found further down the dip than oil, are the results of the ability of water to take gas into solution at the rate of about 3 per cent. by volume at atmospheric pressure and proportionally larger quantities, if available, at higher pressures (measured on the absolute scale). During the year no off-structure wrinkles sufficient to trap conlmercial quantities of oil have been found outside of the other known fields of

Jan 1, 1930

By D. B. Myers

The consistent upward trend in crude oil production prevailing in California throughout the greater part of 1929, was effectively checked in November by a curtailment program instituted by mutual agreement between operators in four of the major fields. This program artificially reduced daily production to approximately the same daily figure as prevailed in December, 1928. The large amount of deep drilling during the later part of 1928 and during 1929 has established a potential, however, which is far in excess of refinery needs in the state. Low prices for crude oil which prevailed in California during 1928 continued during 1929. General curtailment continued in the older fields in San Joaquin Valley. The number of wildcat and exploratory wells drilled throughout California was materially increased, but no major field was discovered unless the recent bringing in of the Ohio Oil Co.'s Recreation Gun Club No. 1 well, near Venice in Los Angeles Basin, during the closing days of 1929 results in such a field. Significant developments during 1929 were: (1) The discovery of three deeper zones in the Santa Fe Springs field known as the O'Connell, Clarke, and Hathaway; (2) Kettleman Hills development and unanimous agreement to restrict production; (3) developments along the Santa Barbara Coast and the drilling of tideland permits; (4) extensions of some of the older producing areas in the San Joaquin Valley; (5) the Lawndale and Santa Barbara Mesa structures, the former discovered in Los Angeles Basin in 1928, the latter in Santa Barbara County in 1929, proved to be failures; (6) intensive exploration throughout the state and the drilling of a large number of deep wildcat wells; (7) discovery of oil by the Ohio Oil Co. in the Los Angeles Basin at Venice; (8) Long Beach and Ventura Avenue fields maintained steady production throughout the year. As a natural sequence to the discovery of high-gravity oil fields in Kettleman Hills and at Elwood in 1928, a tremendous amount of exploratory work was done in 1929 in areas underlain by rocks of lower Miocene age, particularly along the Santa Barbara Coast area, the San Joaquin Valley, and the Salinas Valley, where the Vaqueros and Temblor sands were considered to hold possibilities for production.

Jan 1, 1930

By R. H. Goodrich

Development in this district during the year 1929 was little different from that of any other year despite the somewhat depressed condition of the oil business in general. The year was marked by: (1) An intensive geophysical campaign in the search of deep-seated salt domes; (2) the rather successful exploration and development of lateral sand production on the flanks of some of the older domes. Geophysical Exploration Geophysical work is confined almost exclusively to the torsion balance and seismograph. At the beginning of the year there were approximately 185 individual instruments of all types engaged in the search of structures in the Gulf Coast of Texas and Louisiana. This total includes 3 magnetometers, 83 torsion balances and 100 seismographs. The number of parties operating the torsion balances was 47; seismographs, 20; magnetometers, 3. It is estimated that 4,800,000 lb. of dynamite or other explosives were used in seismic exploration. During the year the torsion balance and seismograph were credited with having discovered the following salt domes: Texas, Danbury dome, Brazoria County, H. & T. B. R. Co., and Clodine dome, Fort Bend County, John Fredricks and Wm. Stanley, Satowsky Survey; Louisiana, Iowa dome, Calcasieu and Jefferson Davis Parishes, T. 9 S., R. 6 and 7 W., and Cameron-Meadow dome, Cameron Parish, T. 14 S., R. 13 W. Because of the secrecy maintained in these developments, it is somewhat hazardous to venture opinion as to the number of salt domes found during one year. The discovery of gas at Mykawa district and at Genoa district, in Harris County, Texas, is considered of more than passing importance, because there is indication in the performance of these two districts that commercial accumulation of oil and gas may be found in the Gulf Coast on structures other than the wore or less definite salt dome type. While it is generally conceded that the accompanying structure in these instances are deeply buried salt domes, it is a fact that neither the seismograph nor the drill have indicated the presence of salt.

Jan 1, 1930

By Alfred H. Bell, Paul F. Simpson

The year 1929 was one of continued activity in the petroleum industry of Indiana and Illinois but the new production obtained has not been sufficient to offset the decline in the production of the old wells. (Table 1). Drilling costs have not changed materially during the year and the prices of crude oil have increased slightly so that the prospects for further testing are good. The total number of completions in Illinois in 1929 (Table 2) was greater than for any year since 1917. More than half of these were in the Dupo field, St. Clair County, and the development of this field was largely responsible for the increased ratio of producers to dry holes in the state as a whole. In the southeastern Illinois field which has produced about 97 per cent. of the state's petroleum the number of completions was greater than in 1928 and the percentage of producers was a little higher. Although a number of scattered wildcat tests were drilled most of them were not located on favorable structure and the only noteworthy discovery was that of a shale-gas horizon at shallow depth in Morgan County in western Illinois where gas has been produced for a number of years from sandstone and limestone. In Indiana the number of completions (Table 2) was only slightly less than in 1928. Most of the new wells were drilled in the southwestern part of the state, which now produces more than 90 per cent. of Indiana's petroleum.

Jan 1, 1930

By R. E. Grim

With the exception of the extreme northeastern part of the state, Mississippi lies wholly within the Gulf Coastal Plains. The largest structural feature definitely proved is the so-called Jackson structure1 in the central part of the state. This structure is mainly the result of the burial of an igneous ridge on the old sea floor. The ridge trended in a northwest direction from about the town of Jackson in Hinds County into southeastern Arkansas. The present structure is the burial of the ridge. Recent detailed surface work by major oil companies has suggested smaller structures in other parts of the state, but so far they have not been definitely proved. Also considerable magnetometer and seismographic work has been done in the northern and central part of the state. The results of the operation of the seismograph are not yet available, but the magnetometer located many "magnetic highs" in this part of the state. Outside of the area of the Jackson structure, the exact cause for this magnetic variation is not known. In a portion of south Mississippi, considerable seismographic work has been done recently in an attempt to locate salt domes. While the details are not available, it has apparently met with little success. Prospecting by districts during the past year may be summarized as follows: Five wells of importance were drilled in the Amory district of east Mississippi. This district comprises all or parts of Monroe, Lee, Itawamba, Prentiss, .Alcorn and Tishomingo counties. Small gas was discovered at about 2500 feet. Several wells were drilled in the. Jackson district which is located in part or all of Hinds, Rankin, Madison and Yazoo counties. Some of these wells were abandoned and one was shut down most of the year

Jan 1, 1930

By J. W. Lewis

This review covers that portion of the area between the Llano mountains and the Red River which lies between Fort Worth and Abilene. The counties and fields included are listed in Tables 1 and 2. During 1929 there was a marked lull in both prospecting and development in this part of Texas. Archer, Coleman, Cooke, Wilbarger and Young were the counties most active. The total gross production of the year was 52,611,000 bbl., 3 per cent. more than for 1928. The production of the Coleman, Cooke-

Jan 1, 1930

By O. G. Bell

While all of the Southwest Texas fields lie within the Gulf Coastal Plain this area may be divided into three subdivisions—the Coastal Plain zone proper, the Reynosa Escarpment zone, and the interior zone. The Coastal zone includes that strip adjacent to the Gulf of Mexico and . extending inland for a distance of about 60 miles and includes the Palo Blanco, Palangana, Piedras Pintas, Kingsville, Agua Dulce, Saxet, White Point and Refugio fields. The Reynosa Escarpment zone includes a Pliocene overlap over older Tertiary sediments lying west of the Coastal zone. The western margin of the Reynosa formation forms a more or less well-defined westward facing escarpment with which the so-called Reynosa Escarpment fields are indirectly related. These fields include those in eastern Zapata, eastern Webb, western Jim Hogg, western Duval, McMullen, Live Oak, Bee, Goliad and Victoria counties. The interior zone includes these fields west of the Reynosa Escarpment which are not in any way related to it and are on separate types of structure. Production data by fields and wells are shown in Table 1. Roma.—During 1928 the Texas Co. completed two small gas wells at 198 ft. on the Roma Structure near the town of Roma on the Rio Grande in Starr County. This gas is of no commercial importance but was used for fuel in drilling other deep tests on this structure. Three dry holes ranging from 3600 to 4200 ft. were drilled; then their No. 4 Guerra, the fourth deep test, was completed during December as a small producer of 37" Bé. oil from a sand at 3560 to 3590 ft. No production was marketed during December but arrangements were being made to handle the output from this well during 1930. This is the first commercial producer in Starr County. Driscoll.—In 1929, Robert Driscoll discovered gas on his Santa Rosalia Ranch in Duval County while drilling water wells. Two sands were developed, one at 2400 ft. and another at 2936 ft. and several gas wells were completed in each, ranging in volume from 15,000,000 to 40,000,000 cu. ft. and in reservoir pressure from 500 to 1,000 Ib. Early in January of 1929, Mr. Driscoll's No. 14 Fee was completed as a 50-bbl. oil producer at 2894 ft. Two other oil producers were completed early in 1929. Mr. Driscoll's death early in the year curtailed develop-

Jan 1, 1930

By W. E. Hubbard

The Panhandle area of northwest Texas embraces the northern portion of the Permian Basin of Texas as well as a considerable portion of the western part of the Anadarko Basin of Oklahoma. For the purpose of this report it will include in addition to the 20 counties of the Panhandle proper the two tiers of counties lying to the south, a total area of about 32,000 square miles. Crossing the Texas Panhandle diagonally from northwest to southeast is the Amarillo Arch, related to which is all of the production discovered to date. Oil Production Up to Jan. 1, 1930, the Panhandle has produced about 125,000,000 bbl. of oil. The peak yearly production occurred in 1927, during which period 49,000,000 bbl. were produced. In 1928 the production fell to 25,000,000 bbl., but in 1929, on account of important discoveries in Gray County, the total increased to 31,000,000 bbl. To date Hutchinson County has produced 64 per cent. of the total. Table 1 shows the total yearly production by counties. The present production of the Panhandle is 100,500 bbl. from 1745 wells or an average of 57.6 bbl. per well compared to a production on Jan. 1, 1929, of 59,748 bbl. from 1468 wells or an average of 40.7 bbl. per well. The peak production of the year occurred during the week

Jan 1, 1930

By R. E. Rettger

The area referred to in this paper is the southern part of the Permian Basin lying in southwest Texas and southeast New Mexico (Fig. I). Those fields lying along the northern rim of the basin; namely, the Panhandle fields, are not included. The fields within this area are

Jan 1, 1930

By H. B. Goodrich

In considering historically oil development in Oklahoma, it must be recognized that basic evolutionary factors interlock and have an effect in common throughout the whole oil industry, regardless of locality or minor problems. Oklahoma, as the third in rank of oil-producing states (Texas being first and California second in production for 1929) has, like the rest, advanced to at least a partial recognition of the words, "Conservation," "Unitization," "Curtailment," "Prora-tion," and especially "Cooperation." Whether through altruism (of which there have been examples) or by exercise of good business common sense, Oklahoma operators realize that the oil business can run itself by cooperative action for the good of all. In this long-continued period of overproduction, Oklahoma has brought the advancing output down to limit of market requirements at least temporarily. Sources of Statistical Data For this paper, figures published by four recognized authorities were consulted. Between themselves these vary only a negligible per cent, in their totals. To be consistent, and on account of earlier availability the estimates published by the Oil and Gas Journal are mainly used herein, supplemented from other public and private sources. General Oil ProdCction in Oklahoma In 1927 Oklahoma's peak of all years was 276,022,024 barrels. In 1928 Oklahoma's total production was 247,500,851 barrels. In 1929 Oklahoma's total production was 252,229,474 barrels. The efforts of proration and curtailment programs on flush and semi-flush districts such as Greater Seminole, Oklahoma City, Logan County and others, with the natural decline of older pools, kept 1929 below 1927, but still the total was greater than in 1928. The total United States production for 1929 is herein taken as estiiated at 1,004,266,723 bbl.† Oklahoma produced 25.1 per cent. Of

Jan 1, 1930

By Anthony Folger, Charles E. Straub

Kansas produced 38,150,878 bbl. of oil in 1928 and 40,658,170 bbl. in 1929, thereby retaining its rank as fourth among the oil-producing states of this country. Production for 1928 was less than that for 1927 (Fig. 1) because of a decrease in the number of completions, but the average initial production per well (Table 1) shows an increase due to the completion of wells of comparatively large capacity in the new Valley Center pool of Sedgwick County. This increase in average initial production per well was further augmented during 1929 by completion of additional wells of comparatively large capacity in the Valley Center pool and the new Greenwich pool of Sedgwick County. Production for 1929 exceeded that for 1928 and threatened to exceed all records except that of 1918, however, production was prorated in

Jan 1, 1930

By F. F. Hintze

Petroleum production in the Rocky Mountain district during 1929 registered a small decline from that of the previous year, conforming with a gradual decrease in the amount of oil produced during the last few years. A number of causes may be mentioned to account for this result, chiefly overproduction in other regions and the apparent desire of operators in this territory to conform to the policy of proration and retrenchment adopted by special agreement among operators in many of the fields. Unit operation has been adopted to control oil production from the Sundance sands in the Salt Creek field, Wyoming, in line with the general effort to stabilize this phase of the industry and prevent excessive drilling of new wells. Another factor which greatly retarded development in the Rocky Mountain region was the executive order of President Hoover issued in March refusing the award of new prospecting permits to future applicants and threatening cancellation of all existing permits upon which actual drilling had not been done as specified by law. Only four states in the Rocky Mountain region are important oil producers. In 1929 Wyoming led with an average daily output of 52,600 bbl., followed by Montana, with 10,730 bbl.; Colorado, with 6500 bbl., and New Mexico with 2700 bbl. daily average. These states bear the following percentage relation to total production in the Rocky Mountain district: Wyoming, 72; Montana, 15; Colorado, 9; New Mexico, 4., (Table 1.) The total average daily production was approximately 73,000 bbl. and the total production of all four states during the year was 26,534,606 bbl. This is 2.7 per cent. of the total oil production of the United States during this period. Colorado Although Colorado is not a large producer of oil and natural gas, its oil operations are widely distributed over the state. The Florence field is one of the oldest oil fields in the country, and there are good reasons for believing that the state will retain its place for many years to

Jan 1, 1930

By Walter S. Lutz, J. T. Griffith

The rainfall during the last six months of 1942 in Scranton and vicinity was 24.06 in.—only 4.35 in more than the average for this district in any equivalent period—yet that rain forced The Hudson Coal Co. to handle 38.8 tons of water for every ton of coal mined. It filled to overflowing, or to a higher level, 14 flooded mine areas holding, in total volume, 8.3 billion gallons of water in storage; brought about a pumpage of 11.4 billion gallons in the months of December 1942 and January, February and March 1943 Half of the total energy generated or purchased (44,322,980 kw-hr.) was required to keep the mines sufficiently free of water to permit the mining of coal during a period of much needed output. Fig. I shows the extent to which this flooding of exhausted and idle properties has proceeded, and is known to be proceeding further, at the upper end of the Northern field. This rainfall (24.06 in.) means 80,559,444 tons of water on approximately 46.2 sq. miles of area tributary to the pumping plants. During the high rainfall period, 72,687,661 tons went underground, being pumped at the stations in this territory. This means an inflow of 88per cent, a runoff of 12 per cent compared with 64 per cent during normal conditions in a normal region. During this period no floods, either surface or underground, had to be dealt with, although the streams and rivers were high on several occasions. In general, the rainfall for the first three months of 1943 can be described as heavy but not abnormal.9 These figures not only indicate the large volumes of water to be handled but, by their very size, they also emphasize that the mine-water problem is not to be conquered, at least from an economical standpoint, by merely buying and installing more and more pumps. Into the solving of this water problem must go much planning, adhering to the principle of keeping the highest percentage of water at the highest possible level for the longest period of time; the storage of huge volumes in sumps capable of being reduced after the flood inflow and at rates less than the inflow; plans for prevention of surface inflow; provision of the minimum of pumping capacity arranged to as nearly 100 per cent pumping load factor as is possible; intercompany joint pumping plants; the conducting of water from one plant to another and from one property to another over distances measured in miles; priorities in power to the threatening situations; and. balance of the necessities and dangers existent in one colliery over another, day by day, when quantities of water are running high. Despite these astronomical figures of water volumes, their disposal to the surface is accomplished reasonably cheaply because, although the annual cost of $575,020 is a large sum, the cost per ton is about 0.1168 cents. Credit for this goes

Jan 1, 1947

By J. T. Griffith, Walter S. Lutz

The rainfall during the last six months of 1942 in Scranton and vicinity was 24.06 in.—only 4.35 in more than the average for this district in any equivalent period—yet that rain forced The Hudson Coal Co. to handle 38.8 tons of water for every ton of coal mined. It filled to overflowing, or to a higher level, 14 flooded mine areas holding, in total volume, 8.3 billion gallons of water in storage; brought about a pumpage of 11.4 billion gallons in the months of December 1942 and January, February and March 1943 Half of the total energy generated or purchased (44,322,980 kw-hr.) was required to keep the mines sufficiently free of water to permit the mining of coal during a period of much needed output. Fig. I shows the extent to which this flooding of exhausted and idle properties has proceeded, and is known to be proceeding further, at the upper end of the Northern field. This rainfall (24.06 in.) means 80,559,444 tons of water on approximately 46.2 sq. miles of area tributary to the pumping plants. During the high rainfall period, 72,687,661 tons went underground, being pumped at the stations in this territory. This means an inflow of 88per cent, a runoff of 12 per cent compared with 64 per cent during normal conditions in a normal region. During this period no floods, either surface or underground, had to be dealt with, although the streams and rivers were high on several occasions. In general, the rainfall for the first three months of 1943 can be described as heavy but not abnormal.9 These figures not only indicate the large volumes of water to be handled but, by their very size, they also emphasize that the mine-water problem is not to be conquered, at least from an economical standpoint, by merely buying and installing more and more pumps. Into the solving of this water problem must go much planning, adhering to the principle of keeping the highest percentage of water at the highest possible level for the longest period of time; the storage of huge volumes in sumps capable of being reduced after the flood inflow and at rates less than the inflow; plans for prevention of surface inflow; provision of the minimum of pumping capacity arranged to as nearly 100 per cent pumping load factor as is possible; intercompany joint pumping plants; the conducting of water from one plant to another and from one property to another over distances measured in miles; priorities in power to the threatening situations; and. balance of the necessities and dangers existent in one colliery over another, day by day, when quantities of water are running high. Despite these astronomical figures of water volumes, their disposal to the surface is accomplished reasonably cheaply because, although the annual cost of $575,020 is a large sum, the cost per ton is about 0.1168 cents. Credit for this goes

Jan 1, 1947

By Edward Griffith

The anthracite industry, which produces about 50 million net tons of coal annually, has been talked of as being able to last for another century; but if the water record of the past century continues into the expected century, this expectation of many years production still to come out of the remaining reserves will not be attained. The industry will be a submerged one in fact as well as in name. A recorded forecast of what has since occurred appears on page 34 of the Mine Inspectors' reports of 1897: It should also be noticed that bodies of water had accumulated in parts of abandoned mines before duplicate surveys of the same were required by law; and as a result we have today to contend with bodies of water, the exact location and position of which are not correctly known. Since that date, 47 years ago, the implications of the foregoing comment have grown enormously. This is shown in Fig. I and in the following table showing flooded and partially flooded areas that have come into existence since the early 1930's in the northern anthracite field: Number of Year Flooded Areas 1932...................... 2 1933...................... 3 1934..................... 3 1935...................... 5 1936...................... 7 1937...................... 9 1938.................... 11 1939...................... 11 1940...................... 11 1941...................... 14 1942...................... 14 1944...................... 26 Similar conditions exist in other fields in the anthracite region. In the period between 1923 and 1940, abandonment of collieries in the southern field resulted in the flooding of approximately 60 sq. miles (30 per cent) of the field. The ahandonment of collieries in this field has imposed additional expense for pumping on the collieries still operating. This condition will be aggravated by the extension of developments and cause suspension of operations if economic conditions do not justify the assumption of additional pumping costs. During the years, the region's rainfall has not altered, but the quantity going inside the mines through breakages in the surface, brought about by extraction of the coal, has increased materially, as indicated by the ratio of tons of water pumped to tons of coal produced underground for one of the large companies in the northern anthracite field: Year Ratio 1920................. 8.4:1 1925.................. 10.6:I I930.................. II.4:I 1935................. 26.2:1 1940.................. 32.7: I 1942.................. 30.3:I The data in Table I shows the total amount of water pumped and its ratio to underground production for one of the large companies in the southern anthracite field, and shows a rapidly growing serious situation. Rainfall quickly affects the workings in all the fields. In mine inspection district 7 of the southern field the rainfall in 1935 was 92,083,000,000 gal. The total water pumped was 36,274,000,000 gal. (39.4 per cent of the rainfall). The operating mines

Jan 1, 1947

By Edward Griffith

The anthracite industry, which produces about 50 million net tons of coal annually, has been talked of as being able to last for another century; but if the water record of the past century continues into the expected century, this expectation of many years production still to come out of the remaining reserves will not be attained. The industry will be a submerged one in fact as well as in name. A recorded forecast of what has since occurred appears on page 34 of the Mine Inspectors' reports of 1897: It should also be noticed that bodies of water had accumulated in parts of abandoned mines before duplicate surveys of the same were required by law; and as a result we have today to contend with bodies of water, the exact location and position of which are not correctly known. Since that date, 47 years ago, the implications of the foregoing comment have grown enormously. This is shown in Fig. I and in the following table showing flooded and partially flooded areas that have come into existence since the early 1930's in the northern anthracite field: Number of Year Flooded Areas 1932...................... 2 1933...................... 3 1934..................... 3 1935...................... 5 1936...................... 7 1937...................... 9 1938.................... 11 1939...................... 11 1940...................... 11 1941...................... 14 1942...................... 14 1944...................... 26 Similar conditions exist in other fields in the anthracite region. In the period between 1923 and 1940, abandonment of collieries in the southern field resulted in the flooding of approximately 60 sq. miles (30 per cent) of the field. The ahandonment of collieries in this field has imposed additional expense for pumping on the collieries still operating. This condition will be aggravated by the extension of developments and cause suspension of operations if economic conditions do not justify the assumption of additional pumping costs. During the years, the region's rainfall has not altered, but the quantity going inside the mines through breakages in the surface, brought about by extraction of the coal, has increased materially, as indicated by the ratio of tons of water pumped to tons of coal produced underground for one of the large companies in the northern anthracite field: Year Ratio 1920................. 8.4:1 1925.................. 10.6:I I930.................. II.4:I 1935................. 26.2:1 1940.................. 32.7: I 1942.................. 30.3:I The data in Table I shows the total amount of water pumped and its ratio to underground production for one of the large companies in the southern anthracite field, and shows a rapidly growing serious situation. Rainfall quickly affects the workings in all the fields. In mine inspection district 7 of the southern field the rainfall in 1935 was 92,083,000,000 gal. The total water pumped was 36,274,000,000 gal. (39.4 per cent of the rainfall). The operating mines

Jan 1, 1947

By Reuel A. Cochrane, Harry H. Angst

The successful exploitation by opencut methods of the low-grade porphyry copper deposits is due to the economical handling of large tonnages. Large tonnages are possible only if the rock material is broken so that the large power shovels can operate with minimum delays. This is particularly true at the New Cornelia mine, where the dense, hard, tough rock material creates problems not encountered in most of the porphyry copper mines. The introduction of churn drills at the New Cornelia for primary drilling, in 1936, necessitated a complete change in the methods of breaking ground as formerly air drills had been used. The blasting operations are of particular interest because of the handling of great quantities of high explosives in safely and efficiently fragmenting the hard rock material. Rock Formations At the New Cornelia mine the rocks are quartz monzonite with a diorite border facies intruding a rhyolitic series. Overlying these formations is a fanglomerate formation composed of boulders of monzonite, diorite, rhyolite, and other types of rock of unknown derivation. (The word "fanglomerate" is used in this paper in referring to the local conglomerate type of rock formations.) The ore body is approximately 4800 ft. long and 2800 ft. wide, and is of the disseminated type. Mineralization occurs principally in the quartz monzonite and to some extent in the adjacent diorite and rhyolite. The principal ore minerals are chalcopyrite, bornite, and a small amount of chalcocite. Over a considerable area the quartz monzonite is extremely hard and siliceous in character, owing to pegmatitic zones of alteration. The hardness of the ground depends on the intensity of the silicification. In a small area in the pit, the monzonite contains an abundance of pyrite accompanied by sericitization and is soft and easily fragmented. This is true also in the remaining oxidized portion of the ore body. The diorite and rhyolite formations, like the monzonite, vary from extremely hard to very soft material, but on the whole are easier to fragment than the monzonite. Jointing is prevalent in all the rock formations and plays an important role in the blasting efficiencies. In the fanglomerate formation, numerous well-defined joints, widely spaced, tend to make the ground blocky when blasted. This is a deterrent to good fragmentation. In the other rocks the joints are more numerous and are closely spaced, except in localized areas where the formations are extremely hard. These descriptions indicate that the lowest blasting efficiency will be obtained in the harder formations, from which the major portion of the mine production is obtained; namely, the monzonite and rhyolite. All rock formations mined at the New Cornelia pit are so hard that excavation

Jan 1, 1943