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By T Wang, D Wang

Photogrammetry-based techniques supported by traditional mapping tools are more frequently used for open pit geotechnical mapping. It fundamentally involves the collection of geological, structural and rock mass data from pit batters when safe to do so. These are essential components for refining and implementing continuous improvements to geotechnical models. The geotechnical model is used to review bench performance, optimise geotechnical design parameters, interpretation and analysis of pit slope stability. This paper is a case study of implementing different pit mapping methods at Mount Carlton gold mine, North Queensland. It critically reviews the tools required, including the Brunton compass, mobile application Clino, geotechnical data mapping software CloudCompare (2015) and Sirovision software. The review compares the image precision, structural measurements and data analysis. The review also underlines mine site management philosophy for safe geotechnical data collection to identify in-pit geotechnical hazards and the mitigation of potential slope instability. Sirovision is a remote sensing system for site geology mapping and interpreting geotechnical characteristics of exposed mining faces. The system utilises off-the-shelf digital SLR cameras to capture stereo photographs of the rock face and uses the latest image processing technology to generate accurate 3D models. These 3D models are digitally analysed using computational geometry to extract unbiased and accurate geological and geotechnical data. CloudCompare processes high accuracy 3D dense cloud rock surfaces reconstructed with photogrammetry software to extract the geological planes using the FACET or Compass plugins. The major discontinuity sets can be observed and the orientation (dip/dip direction) obtained from the algorithm is accurate and reliable for geotechnical assessment, including kinematic and rock slope stability analysis.

Nov 29, 2022

By E. H. Izen

A thermal imaging borehole probe was designed and fabricated for the purpose of obtaining thermal images, through smoke, of objects and people in underground mines. The effort was basically unsuccessful; electrical noise, and possibly thermal noise, interferred with the desired signals to the extent that spatial resolution in the images was unacceptable.

Jan 1, 1980

By Achilles Dutra, Everton Santos, José Oliveira

The beneficiation of phosphate ores by froth flotation is the most efficient process used to separate apatite from gangue minerals like calcite, dolomite and quartz. However, the similarity of surface properties between apatite and calcite generally lead to non-selective adsorption of reagents, rendering the selective separation of these minerals a worldwide problem. The phosphate deposit of Itataia, State of Ceará, Brazil, studied in the present work, presents a complex mineralogical composition having uranium associated with the apatite mineral. The main gangue minerals are calcite and quartz. The bulk flotation of apatite and calcite with anionic collectors in an alkaline medium followed by the selective flotation of calcite at pH 5.5 using phosphoric acid as well as citric acid as depressant have been suggested for this ore. This paper presents the results of contact angle measurements obtained using jojoba oil, a natural reagent composed mainly of gadoleic acid (C20:1) and long-chain fatty alcohols (eicosenol and docosenol), as an alternative collector for the selective separation of apatite and calcite minerals. The hydrophobicity studies were carried out using a computer controlled contact angle goniometer. Additionally, the collector adsorption was evaluated via electrophoretic mobility and FTIR measurements. The results indicated that a high selectivity can be obtained by using jojoba oil as collector in a slightly acid pH range, without the use of depressant. The best results were achieved with a jojoba oil concentration of 200 mg.L-1 at pH 6.5, where the apatite was fully hydrophilic and calcite showed a high hydrophobicity (? > 60 º).

Jan 1, 2014

By V. Vern Hutchison

This selected list contains 829 entries with citations to Bureau of Mines publications related to petroleum and natural gas, which were released during the 1961-1970 period. Some entries are multiple in nature, resulting in a total of 881 citations.

Jan 1, 1972

By A. D. David

The object of this paper is to reduce to the simplest possiblc discussion the recent developments in refinery technology without resorting to detailed technical descriptions of the various items. During the year 1929, the most noteworthy tendencies have been towards the installation of more flexible plants, more unified operations, more balanced performance and greater fuel economy. In no other year in the history of petroleum refining has the industry witnessed to as great a degree the crystallization of so rnany developments in almost every phase of the art. Economic pressure has been the controlling factor, supplemented however by a market demand for more volatile anti-knock gasoline and higher quality of lubricating oils, resulting from the extended use of high-compression motors. Catalytic Hydrogenation Possibly the outstanding achievement during the year has been the beginning of construction of plants by the Standard Oil Co. of New Jersey for the catalytic hydrogenation of the so-called heavier and inferior petroleum oils to produce therefrom not only high yields of anti-knock gasoline, but also lubricating oils equal in quality to the best grades obtainable. It is reported that the plants will operate at a pressure of 4000 lb. or higher and temperatures in excess of 900" F. will be used. The hydrogen required for the conversion will be produced from refinery gases. This type of processing will doubtless be an important factor in balancing future operations; in other words, it can be used to eliminate present waste products and permit production of high-grade products from low-grade crude. Improvements in Lubricating Oils Another important development during the past year has been the extended use of vacuum stills, making possible the production of lubricating oils from what was formerly classed as "fuel-oil crude," or crude from

Jan 1, 1930

By C. Musingwini

The South African mining industry continues to be a major source of employment at a time when at least 25 per cent of the working age population is unemployed. At the same time the industry faces a skills shortage in many of the disciplines necessary for its future health. The University of the Witwatersrand, University of Pretoria, University of Johannesburg, and University of South Africa have historically produced mining graduates for the South African industry, with any shortfall being met by the recruitment of overseas graduates. More recently the global shortage of engineers and other mining industry professionals has seen a reversal of this trend and a very significant emigration of well-educated and highly skilled personnel. The traditional career path for mining graduates is in production and mine management. However, there is the parallel and possibly more pressing need for specialized skills in such fields as ventilation, rock engineering, mine planning, mineral resource evaluation, and mineral asset valuation. It is in these essential areas that chronic shortages continue to hamper the development of the industry and may well frustrate its ambitions to be safe, healthy, and profitable into the future. The permeability of skills across sectorial boundaries within the mining industry requires that skills shortages in the platinum sector are not looked at in isolation, but within the context of the entire industry. This paper reviews the efforts being made by the universities at both undergraduate and postgraduate levels to meet the needs of the South African mining industry, in terms of the required numbers and the range of specialized skills.

Jan 1, 2012

By Laurance L. Oden, Jack C. White, Alan D. Hartman

The U.S. Bureau of Mines, under a Memorandum of Agreement with the American Society of Mechanical Engineers (ASME), established design criteria for a facility to field residues from municipal waste combustion. This facility, which is available to potential users on a cost-sharing basis, is also applicable to a variety of inorganic waste materials from smelting or melting operations. The design consists of a mechanical feed handling system, electric arc melting furnace, fume-off gas handling system, and thermal oxidizer for final off gas treatment. Screw conveyors and a bucket elevator deliver up to 2,000 Ib/h of minus I-in material to a three-phase electric arc melting furnace. This unique 800-kVe A furnace has a water-cooled shell and roof to minimize interaction of the melt with the refractory lining. The volume of the hearth below the slag taphole is approximately 1.2 st of steel. The furnace is sealed, allowing atmosphere control within the furnace and fume duct by nitrogen or inert gas injection. A jet-pulsed baghouse removes particulate from the off gas and serves as an acid gas scrubber. The clean off gas is heated to 1,800' F for 1 s in a propane-fired thermal oxidizer before being vented to the atmosphere.

Jan 1, 1993

By D. A. Aranda-Regino, C. Gómez-de-la-Garza, J. Ramírez-Cuellar, L. A. Leduc-Lezama

The Pickling Line Tandem Cold Mill (PLTCM) at Ternium’s Pesqueria plant with a 5 stands, 6 high configuration started in 2013. At the time of the start up the work roll specification and grinding practices were stablished following a low risk policy to be able to sustain any start-up associated accident. Once a stable operation has been achieved both these policies are being modified to improve productivity and reduce costs. The specified hardness of the rolls has been increased and efforts are being made to optimize the grinding according to the rolling campaign length and materials. The fatigue damage in work rolls, after rolling and its removal by grinding was followed by hardness measurements made at the end of the rolling campaign and after grinding. Softening of the rolls after rolling was found mainly in final stands to be related to the averaged stress experienced during the campaign, the original roll hardness was recovered after grinding. Hardness evolution was also followed after each grinding step finding that the total amount of grinding could be reduced. The grinding practice was modified accordingly for the first stands and the yield of work rolls in them has improved.

Oct 1, 2019

By Chas. A. Ashburner

The occurrence of oil- and gas-springs in the State of New York has been a fact of historical record since 1627, when the existence of the Cuba oil-spring was first recorded. The utilization of natural gas at Fredonia in 1821 attracted the attention of the public to the possibility of obtaining an illuminating gas by digging and drilling into the rocks. No active search was made, however, for oil or gas by the drilling of wells until after the discovery of commercial oil in Pennsylvania in 1859. In 1862 a well was drilled at Bradford, McKean County, Pennsylvania, but a few miles south of the New York state line, to the depth of 200 feet, in search of the oil-sand which had been found at Titusville, Oil City, and at other points in Western Pennsylvania. Immediately subsequent to this, other wells were drilled in search

Jan 1, 1888

By Bob J. MacDonald

The Cape Breton Development Corporation is a federally owned Crown corporation in Canada that operates two coal mines the Prince and Phalen Colliery in the Province of Nova Scotia. Retreat longwall mining was first introduced to the shallower workings (I 80m) of Prince Colliery in the early 1980's. Phalen Colliery started longwall retreating in 1987 and since that time has extracted twelve panels. In 1993 there had been a total of eight longwalls varying in widths from 140-230m mined in Phalen Colliery that is on the Phalen Seam. Up to this point there were only minor ground control problems on the faces except for one of the earlier longwalls that was mining a split seam. There is some interaction on Phalen workings from remnant structures in the overlying Lingan and No. 26 Collieries which worked the Harbour Seam. Induced abutments loads along pillar edges have been observed and resulted in poor face conditions when mining the Phalen Seam. The ninth panel, 6 East was the first panel to suffer a major roof fall from the First Major Weighting. This was also the first panel to undermine a paleo sandstone river channel named the Lower Sandstone Unit (LSU). For the first time in Phalen's history subsequent longwalls began to experience periodic weighting events. The 6 East panel suffered a number of periodic weightings and on two occasions had to use foam cement to fill the cavities that resulted. On the next east side panel, 7 East, there were numerous periodic weighting events, but interestingly there was no significant First Major Weighting. 7 East was the first 260m wide panel and all others were 230m or less. This longwall was 3,400m long and began producing in December of 1994 and was still cutting coal in May of 1997. There were five significant roof fall events on this panel, three of which required foam cement to fill the cavities. Of these three the interruption to production varied from four days to seven months. There were definite precursors to each of the weightings including: 1) an increase in audible noise (termed bumping) on the face, 2) supports went rapidly into yield, 3) roof convergence increased, 4) water percolated from the face roof strata, and 5) severe spalling of the coal occurred resulting in increased tip to face distance. Longwall face weightings are a result of geomechanical factors and cannot be avoided However, the loss of roof control is a different matter and highly subjective to operational procedures. The causes of weightings, their magnitude and impact on the mining at Phalen have been investigated. The following factors have been identified as relevant to these occurrences. 1. The influence of pillars in the overlying Harbour Seam workings. 2. Location of the LSU relative to the Phalen Seam. 3. Thickness of the LSU. 4. Pressure arch effect from the adjacent gobs. 5. Poor operational practices on the longwall including: a) slow rate of retreat; b) inadequate supply of pump pressure to the hydraulic supports; c) premature yielding of the yield valves; and d) poor face alignment practices. This paper will review the events that took place on the 7 East longwall and show that the Lower Sandstone Unit is the primary cause of the weightings. However, other factors contributed to the loss of roof control and the formation of the roof cavities.

Jan 1, 1997

By Jeffery L. Kohler, Harvinder Singh, Jon G. Bredeson

A survey of electromagnetic noise reports was performed and a summary of the results are given. Industrial concerns were surveyed for techniques to minimize the effects of electromagnetic noise and are presented. The common types of communication links used in mines today are presented. A mathematical development was presented which determines the probability of bit errors versus distance for various types of communication links designed for in mine use. The probability of undetected errors for the protocols of the communication links is given together with burst error detection.

Jan 2, 1981

By Ben Habermann

"The object of the work described in this paper was to increase the understanding of the relation that capillary pressure of a rock, hydro-dynamics, and accumulation of oil in stratigraphie traps have to one an-other. The hydrodynamic oil-water tilt equation is derived by considering the two vector gradients involved: (1) buoyancy of oil in water and (2) hydraulic gradient.Recent theories show the necessity for oil to have a continuons phase in the reservoir rock in order to mi-grate; this fact applies to hydro-static as well as to hydrodynamic conditions. Hydrostatically, the displacement pressure of the rock deter-mines the amount of oil that can be trapped behind a permeability barrier. If the buoyancy of oil in water exceeds the displacement pressure, oil will migrate up-dip; an oil trap will be formed where displacement pressure is greater.In stratigraphie traps the pressure drop caused by moving water is positive when its direction is down-dip, helping accumulation; and it is negative when its direction is up-dip, forcing the oil into the tighter section of the reservoir. Theoretically, pro-vided we have data such as: (1) the displacement pressure of an up-dip permeability pinchout, (2) density difference between the oil and water in place, and (3) the direction and magnitude of the hydrodynamic gradient (if any), the possible extent of a stratigraphie oil accumulation down-dip can be predicted.To test the above theory sample cores from three wells in the Denver Basin were analyzed and the oil column that could be held under hydro-static conditions was calculated. After the hydrodynamic influence was considered, the results were compared with actual field data.The significant fact shown by this investigation is that the calculated oil column in one reservoir very closely approximates the actual extent of the oil column in a well. Also in accordance with the theory, the capillary pressure caused by the buoyancy of the oil column exceeded the measured displacement pressure on core samples from another productive field. For very tight shaly sand and questionable oil shows, the interpretation of data is very critical, as shown by experiments on core samples from a third field."

Jan 1, 1960

By M. D. Marshall

This handbook is for the engineer or person responsible for the storage and removal of material from bins and silos in the minerals industry. The objective of the handbook is to prevent bin-related accidents by eliminating problems which require workers to enter bins. It provides basic information on handling materials so that knowledgeable decisions can be made on bin design and accessories to minimize flow stoppages. Materials are classified in terms of their flowability, and bin design and accessories suggested for each classification. A method for classifying a material is also given, and the various types of material flow aids reviewed. Safety around bins is the basic theme of the handbook. Federal regulations are reviewed and additional suggestions presented to prevent bin accidents. New equipment for releasing material hang-ups is reviewed.

Jan 1, 1984

By H. M. Morse

Tinsley Oil Field.—Mississippi joined the oil-producing states when on Sept. 13, 1939, the Union Producing Company's G. C. Woodruff well No. 1, sec. 13, T. 10 N., R. 3 W., Yazoo County, was completed after drilling plug at 4540 ft. in the Woodruff sand of the Eutaw formation of Cretaceous, producing 300 bbl. per day of 34.4" gravity oil through a ¼-in. choke, with a gas-oil ratio of 80 to 1 and bottom-hole pressure of 2045 lb. This was the discovery well in the Tinsley oil field. The well was drilled to a total depth of 4567 ft. and no salt water was encountered. The sand underlies the Selma chalk formation. Nine producing oil wells and one dry hole were drilled and completed by the end of 1939. Two producing sands have been found in the Eutaw and a third sand in the top of the Tuscaloosa formation, called the Woodbine sand in Louisiana and Texas. Faulting is an important factor in the Tinsley field. Total oil production has been approximately 250,000 bbl. from the nine flowing wells. Total depth to top of productive zone was 4540 ft.; to bottoms of productive wells, 4580 ft. Net thickness of the producing formation is 20 to 40 ft., and its porosity is 24 per cent. The deepest zone tested was the Tuscaloosa, in which the depth of hole was 6112 feet. Six hundred and forty acres has been proved for oil production. Jackson Gas Field.—The Jackson gas field has shown a steady decline in the number of wells but the pressure has been maintained. This field is a perfect example of a water-driven field and the time of wells going to salt water is predictable. Five wells were drilled in the Jackson field, of which only one produced. Amory Gas Field.—Interest was renewed in the Amory gas field, where a new well was started in the fall of 1939. Geological Formations.—The deepest well drilled in 1939 was the Willmut Gas and Oil Company's Cleve Love S. F. Johnson No. 1, sec. 29, T. 6 N., R. 1 W., Hinds County. This well encountered the Lower Cretaceous, Trinity series from 3770 to 6422 ft.; Lower Mesozoic from 6422 to 6484 ft. The geological correlations and nomenclature of the formations in Mississippi are shown in the accompanying strati-graphic section.

Jan 1, 1940

By H. M. Morse

Tinsley Oil Field.—Mississippi joined the oil-producing states when on Sept. 13, 1939, the Union Producing Company's G. C. Woodruff well No. 1, sec. 13, T. 10 N., R. 3 W., Yazoo County, was completed after drilling plug at 4540 ft. in the Woodruff sand of the Eutaw formation of Cretaceous, producing 300 bbl. per day of 34.4" gravity oil through a ¼-in. choke, with a gas-oil ratio of 80 to 1 and bottom-hole pressure of 2045 lb. This was the discovery well in the Tinsley oil field. The well was drilled to a total depth of 4567 ft. and no salt water was encountered. The sand underlies the Selma chalk formation. Nine producing oil wells and one dry hole were drilled and completed by the end of 1939. Two producing sands have been found in the Eutaw and a third sand in the top of the Tuscaloosa formation, called the Woodbine sand in Louisiana and Texas. Faulting is an important factor in the Tinsley field. Total oil production has been approximately 250,000 bbl. from the nine flowing wells. Total depth to top of productive zone was 4540 ft.; to bottoms of productive wells, 4580 ft. Net thickness of the producing formation is 20 to 40 ft., and its porosity is 24 per cent. The deepest zone tested was the Tuscaloosa, in which the depth of hole was 6112 feet. Six hundred and forty acres has been proved for oil production. Jackson Gas Field.—The Jackson gas field has shown a steady decline in the number of wells but the pressure has been maintained. This field is a perfect example of a water-driven field and the time of wells going to salt water is predictable. Five wells were drilled in the Jackson field, of which only one produced. Amory Gas Field.—Interest was renewed in the Amory gas field, where a new well was started in the fall of 1939. Geological Formations.—The deepest well drilled in 1939 was the Willmut Gas and Oil Company's Cleve Love S. F. Johnson No. 1, sec. 29, T. 6 N., R. 1 W., Hinds County. This well encountered the Lower Cretaceous, Trinity series from 3770 to 6422 ft.; Lower Mesozoic from 6422 to 6484 ft. The geological correlations and nomenclature of the formations in Mississippi are shown in the accompanying strati-graphic section.

Jan 1, 1940

Objectives ? New deposits can be found in mature Mining CampsNew Camps ? Volcanogenic Massive Sulfide (VMS) deposits ? polymetallicpolymetallicexamples are desirable exploration targets examples ? Genetic and exploration models for VMS deposits are robustrobust ? subtle but important differences exist between deposits and districts ? sometimes ??neglectedneglected??in resource modeling and exploration efforts ? ReRe-evaluation of a prominent existing camp is rewarding ? update on the exploration strategies currently being applied on a practical level The Falconbridge-Alexis approach includes GoCAD modelling

May 1, 2006

By C. C. McDermond, Others, B. N. Zavoico

Production of crude oil in Venezuela for the year 1937 was 186,653,-916 bbl., as compared with 155,228,982 bbl. produced in 1936, an increase of almost 31,500,000 bbl. The oil-field strike, which started on Dec. 14, 1936, lasted until Jan. 25, 1937, when a total of 10,000,000 bbl. of production was estimated to have been lost (5,750,000 bbl. in 1936 and the remainder in 1937). Of the total of 186,653,916 bbl. produced in 1937, the Lagunillas field contributed 45.6 per cent, a drop of approximately 10 per cent under 1936 figures; Tia Juana, 14.3 per cent; Quiriquire field, 14.0 per cent; La Rosa area, 13.3 per cent and the Mene Grande field, 7.6 per cent, these being the five leading contributors of the year's production. Detailed production figures by fields and by companies are shown on Table 1. Of the total production of Venezuela the following four major companies accounted for the greater proportion: Standard of Venezuela and Lago Petroleum Corporation together, 48.3 per cent; Shell, 37.4 per cent and Venezuela Gulf, 14.0 per cent. At the end of the year, 2491 wells were producing, of which number 1291 wells were pumpers, or about 52 per cent. Production The accompanying statistics of production record of Venezuela oil fields from its inception to Dec. 31, 1937, shown on Table 2, indicates that the cumulative production reached 1,503,283,228 bbl. In order of importance, Lagunillas leads all the fields, having accounted for about 50 per cent of Venezuelan production, followed by La Rosa area, which produced about 21 per cent; Mene Grande, which produced about 13 per cent, and Quiriquire, which produced 6.5 per cent. Table 3 shows the age of each field. Mene Grande is the oldest, having produced for 24 years; Tarra is next, 21 1/2 years old, and El Mene third, 171/2 years. The gravity of the crude from the various fields, also shown on Table 3, remained unchanged, the only addition being the new Tia Juana field, which averages 15.6' A.P.I. Table 4 shows the method of production by fields as of Jan. 1, 1938; at the end of the year 2491 wells were producing, compared with 2005 wells producing at the beginning of 1937, or an increase of 486 wells. The completions for the year reached 512. Of the 2491 wells producing crude oil, 1291 wells, or approximately 52 per cent, were pumping, 925 (approximately 37 per cent) were flowing naturally and 275 (11 per cent) were on

Jan 1, 1938

By B. B. Cox

Since our last review of Iraq,' considerable progress has been made not only in exploiting Iraq's potential resources but in building pipe lines to carry the oil to the Mediterranean. No new fields were discovered in 1933. The Naft Khaneh field, discovered in early 1927 by the Khaniqin Oil Co. (subsidiary of the Anglo-Persian Oil Co.), continues to supply the local markets through the Rafidain Oil Co. Kirkuk field, discovered by the Turkish Petroleum Co. Oct. 14, 1927, remained shut in pending the completion of the Mediterranean pipe lines, and the Qaiyarah field, discovered by the same company on Oct. 13,1927, was abandoned in 1928. The principal development of interest during the year was the progress made on construction of the Iraq Petroleum Company's 1152-mile pipe line from Kirkuk to the Mediterranean. The line is double 10-in. and 12-in. pipe for 156 miles west of Kirkuk, where the parallel lines bifurcate, one leg going through British mandated territory to the new port of Haifa and the other through French mandated Syria to Tripoli. Each line may be operated independently of the other. There are three double stations on the Kirkuk-Haditha portion, four single stations on the Tripoli leg, and five on the Haifa in addition to a relief station in the Jordan Valley. Except for the Jordan Valley section and two other short stretches on the Haifa leg where pressures are exceptionally high, the line is single. Sea loading lines will be used exclusively at Tripoli and both sea loading lines and dock loading will be employed at Haifa. All pipe was welded and buried before the end of December, 1933. It is anticipated that enough stations will be completed to make 50 per cent capacity operation possible some time during the latter half of the current year. Some months will then be required in which to fill the line, so that if terminal facilities are ready and no unexpected emergencies arise, partial daily deliveries of Iraq crude may be received at the Mediterranean some time during the final quarter of the current year. Capacity operation of 84,000 bbl. per day is not anticipated much before the middle of 1935. Oil and Gas Production No gas is produced commercially and, except for Naft Rhaneh production, no crude is marketed. Although the Turkish Petroleum Co. and

Jan 1, 1934

By R Young

Independent Project Analysis (IPA) is in the business of benchmarking the performance of capital projects on behalf of owner companies in the processing and extractive industries. IPA assesses between 500 and 800 projects each year. The projects are conducted globally and range in size from about $1 million to over $30 billion. Using the data, we are able to benchmark the performance of Australian projects against the rest of the world. This presentation focuses on the performance of large (greater than $100 million) projects that involve chemical or thermal processing.We regularly hear calls for more processing to be conducted in Australia but on the other hand industry leaders are concerned about the poor success rate of solids processing projects in Australia. Data gathered by IPA indicates that there is good reason for the concern. Out of a sample of 31 large processing projects conducted in Australia, 23, or 74 percent, were classed as failures. This performance is significantly worse than for similar projects in other parts of the world. The presentation analyses why the performance is worse and demonstrates that many of the reasons behind the failures were manageable by the project team. Furthermore, members of the project teams on at least half the failed projects knew that the projects were on a path to failure before the project was authorised but could not be heard.The presentation discusses how large projects that involve process design and, in many cases, new technology, need to be set up for success. *This is an abstract only. No paper was prepared for this abstract.*

Aug 8, 2011

By H. F. Winham

THE history, development, subsurface geology, production, economics and estimated reserves are discussed in this paper. The Magnolia structure is an anticline with a known maximum structural relief at 372 ft., and the areal extent of the producing acreage is 4494 acres. Production is obtained from the Smackover oölitic lime and 116 successful wells have been drilled. The field, which was developed on 4o-acre spacing, has been under strict control. It is believed to be producing with a strong water drive. To date it has produced more than eighteen million barrels and the estimate of ultimate recovery is 220 million barrels. EARLY HISTORY The Magnolia field is in Columbia County, Arkansas, T. 17 S., R. 19 and 20 W. Various geologists had long been interested in this general area, and as early as 1921, John F. Magale was able to define a surface structure. The first wildcat, one of the first in Columbia County, was drilled in 1923 by Mid-States Oil Co., in sec. 10, T. 17 S., R. 20 W. This well was about 1 ½ miles northwest of the Kerlyn Oil Company's discovery well and was based on surface geological work done by jewel and Dobie. Subsequently, several shallow wells that were not carried below the Upper Cretaceous beds were drilled in the immediate area of the discovery well, but none of them contained any commercial showings of oil or gas. In the latter part of 1935, Elam and Magale (or Southwood) Garrett No. I was located in sec. 13, T. 17 S., R. 20 W., ¾ mile east of the discovery well. It was drilled to a total depth of 4018 ft. in the lowermost Glen Rose beds but failed to obtain any showings of oil or gas. Interest had been stimulated in this general area, however, by the discovery of several oil fields, mainly Glen Rose oil production in the Rodessa field in Louisiana in 1935, Smackover lime production in Snow Hill in May 1936, production from the Cotton Valley formation in Schuler in 1037, and Smackover lime production from the Buckner field in November 1937. With this background and subsequent seismic work, which was carried on partly because the old shallow wells drilled in the township had shown evidence of closure in the Upper Cretaceous beds, the discovery well, Kerlyn Oil Company's Barnett No. I, sec. 14, T. 17 S., R. 20 W., was originally projected to a total depth of 6300 ft., to test the equivalents of the Morgan sands of the Cotton Valley series, then producing at Schuler. The well was carried to a total depth of 6325 ft. and tested the objective beds without finding commercial production. In the meantime, however, one well had found production in the Jones sand and another in the Smackover lime at Schuler. Kerlyn immediately made arrangements to deepen the Barnett well to the Smackover lime. The top of the Smackover lime was encountered at 7618 ft. and the well was cored and drilled to a depth of 7740 ft.

Jan 1, 1942