Humble Oil Research Articles

Debye Award

Robert S. Mulliken, emeritus distinguished professor at the University of Chicago, has been named by the American Chemical Society to receive the $2000 Peter Debye Award in Physical Chemistry for his work in molecular chemistry and physics. The award, established last year under the sponsorship of the Humble Oil & Refining Company, will be presented at the Society's national meeting in Los Angeles next April.

Interfacial Tension of the Methane-Normal Decane System

STEGEMEIER, G.L., JUNIOR MEMBER AIME, SHELL DEVELOPMENT CO., HOUSTON, TEX. PENNINGTON, B.F., JUNIOR MEMBER AIME, HUMBLE OIL AND REFINING CO., HOUSTON, TEX., BRAUER, E.B., JUNIOR MEMBER AIME, UNION OIL CO., ABBEVILLE, LA., HOUGH, E.W., U. OF TEXAS, AUSTIN, TEX. Abstract Interfacial tension divided by the difference in density between the liquid and the vapor phases was determined experimentally by the pendant drop method on several isotherms in the two phase region below the critical point for the methane-normal de can e system. The density difference data of Sage and Lacey was used in the calculation of inter facial tension. Both inter facial tension and interfacial tension divided by density difference were found to vanish at the critical point. Interfacial tensions of less than one dyne/centimeter were observed as far as 1,000 pounds per square inch below the critical pressure. EXPERIMENTAL PROCEDURE The interfacial tension divided by the density difference for the methane-normal decane system was determined at the 100 degrees, 130 degrees, 160 degrees and 190 degrees F isotherms, from pressures of about 1,000 psi to the critical pressure, which is more than 5,000 psi for these isotherms. Particular emphasis was placed upon the investigation at pressures slightly below the critical pressure where the interfacial tension is less than 0.5 dyne/cm. Volumetric properties in the two-phase region, including the critical pressures and temperatures, were taken from the work of Sage and Lacey. The experimental pendant-drop technique used for the determination of interfacial tensions at high pressures incorporated the ideas of Michaels and Hauser, Hough, et al, Walker and Heuer. In addition, the technique for determination of extremely small interfacial tension by Jennings was utilized in the region near the critical points. A detailed description of the apparatus is given in a dissertation by one of the authors. Cleaning operations on the stainless-steel sample system included successive washings with chromic acid, tap water and, finally, distilled water. Subsequent cleanings were performed with re-distilled normal pentane, which had an extremely low residue upon evaporation. Specific composition requirements necessitated a fairly precise sample introduction although, for a two-phase, two-component system, the composition of each phase is completely determined if pressure and temperature are controlled. The normal decane was delivered into the evacuated sample system as a liquid from a burette. The methane was then introduced into the system from a calibrated isothermal container, so that pressure differentials could be used to determine the amount introduced. High pressures were obtained by compressing the sample with a mercury injection pump until the critical pressure was reached for the particular isotherm being studied. Experimental data were then obtained for specific pressures by first decreasing the pressure slightly so that two phases would appear, and then photographing a drop at that pressure. Subsequent photographs were made at increments throughout the pressure range. SPEJ P. 257^

Bigenerina humblei and the Humble H. L. Ellender No. 1, Lirette Field, Terrebonne Parish, Louisiana: ABSTRACT

ABSTRACT The Humble Oil and Refining Company, H. J. Ellender No. 1, sec. 32 T. 19 S., R. 19 E., Lirette field, Terrebonne Parish, Louisiana, is the type locality for Bigenerina nodosaria directa, Cibicides carstensi, Uvigerina lirettensis, Globorotalia fohsi fohsi and Globorotalia mayeri, stratigraphically important Miocene marker species described by Cushman and Ellisor (1939). Globorotalia fohsi fohsi, ranging in the Gulf Coast from the Cibicides carstensi opima Zone upward through the Bigenerina humblei Zone, has been used extensively throughout the world for purposes of intercontinental correlation of Miocene deposits. Ellisor (1940) reported Bigenerina humblei. Uvigerina lirettensis and Globorotalia fohsi fohsi at 9,612 feet, the sample depth from which she and Cushman had earlier described Globorotalia fohsi fohsi and Globorotalia mayeri. Additional deeper drilling and later work have proved that the Humble, Ellender No. 1 penetrated beds no older than the Bigenerina nodosaria directa-Cibicides carstensi Zone. The deepest well in the Lirette field, the Humble, H. J. Ellender No. 6 (also located in sec. 32), drilled to 13,500 feet, did not reach the Textularia stapperi Zone which overlies the Bigenerina humblei Zone. In order to establish the point that Bigenerina humblei could not have occurred at 9,612 feet in the Lirette field, and that the Humble, Ellender No. 1 should not be considered a valid type locality for Globorotalia fohsi fohsi and Globorotalia mayeri, cross section A-A has been constructed to illustrate correlations between Raceland field, Lafourche Parish, and Bay Baptiste field, Terrebonne Parish. The section depicts the general downdip (coastward) thickening of the Miocene section and the tremendous sedimentary accumulations encountered on the downthrown sides of the large growth or depositional faults typical of the area.

Stimulation of Deep Gas and Gas-Distillate Wells

Abstract This paper discusses recently developed gas and gas-distillate producing wells, deeper than 10,000 ft, in West Texas and Southeast New Mexico. High bottom-hole pressures and temperatures above 200F require modification of conventional completion and stimulation techniques. The problem of formation damage due to solid infiltration from drilling fluids and cement slurries is particularly severe. The use of high-density brines as completion fluids is described and recommended to minimize such formation damage. During completion, mud dispersal and removal acids are usually employed to clean up the critical area next to the wellbore. In case of severe permeability damage, it may be necessary to employ supplementary stimulation treatments using acids with retarded reaction rates. Pressure limitations usually require that such treatments be conducted through tubing. When treating acids can be pumped down the casing, utilization of large-volume, high-injection-rate treatments have resulted in increased benefits. Such treatments in the Azalea Devonian field have proven equivalent to fracturing treatments employing propping agents. Comparative lab tests of post-treatment fracture flow capacities indicate that propping sand may undergo crushing or embedment when subjected to high overburden pressures. Although the use of malleable propping agents such as walnut shells or aluminum pellets often results in considerable improvement in productive capacity following fracturing, even better results sometimes are obtained with acid. Nonuniform acid solubility of the fracture faces results in self-propping, thus providing highly permeable flow channels which are unblocked by propping material. High bottom-hole temperatures require the use of special inhibitors to avoid excessive corrosion of metal well equipment. In some cases, the problem of gyp deposition resulting from contact between spent acid and incompatible brine has been overcome by the use of suitable chelating chemicals. Case histories are included, illustrating treating procedures and results obtained under various circumstances. Correlation of reservoir conditions and treatment data have made possible the evaluation of various stimulation methods and selection of optimum treating techniques. Introduction Well stimulation has played an important part in the development and exploration of deep gas reservoirs in the West Texas-Southeast New Mexico area. Most of the recent activity has occurred in the Delaware basin, Sheffield channel, and in the Val Verde basin area. Two important West Texas discoveries, both near the eastern mouth of the Delaware basin in Pecos County, have triggered a new era of deep search throughout the region. Mobil Oil Co.'s No. 1 Kathleen Moore was completed in the Pennsylvanian at 15,041 to 15,047 ft for a calculated open flow of 102 MMcf/D for the discovery of the Rojo Caballos pool. Shut-in bottom- hole pressure was reported to be 12,590 psi. About 20 miles southwest of the Mobil well, another strike was made in The Atlantic Refining Co. No. 1 Kelly, to inaugurate the Hershey pool. This well became the deepest producer in Texas when it potentialed a combined flow of 52 MMcf/D from the Fusselman, Devonian and Montoya between 15,800 and 16,680 ft. Another significant gas discovery was the triplycompleted Shell Oil Co. and Humble Oil and Refining Co. No. 1 Blackstone-Slaughter in the Yucca Butte area, five miles southeast of Sheffield. This well had a calculated absolute open flow of 5.6 MMcf/D from the Pennsylvanian detrital at 8,190 to 8,310 ft, 12 MMcf/D from the Connell at 9,993 to 10,012 ft and 16.5 MMcf/D from the Ellenburger at 10,050 to 10,092 ft. Gas-distillate ratios were 67,000:1 for the Pennsylvanian, 16,500:1 for the Connell and 22,600:1 for the Ellenburger. Other important deep gas pools in the area under consideration include the Vinagerone, Brown-Bassett, Puckett, Emperor, Reeves, Remuda, Azalea, Henshaw, Lancaster Hill, Baggett Ranch, Kermit, Cobblestone, Joe T., Custer, Midland Farms, Jack Herbert, Vacuum, Stiles, Gladiola, Scharb, King, Lusk, Denton, Lea, Mescalero and Coyanosa. JPT P. 841^

Pressure Maintenance Operations in the Sharon Ridge Canyon Unit, Scurry County, Tex.

Abstract The Sharon Ridge Canyon Unit is a pressure maintenance project using fresh surface water injected on a peripheral pattern. Canyon Reef limestone of Pennsylvanian age, occurring at approximately 6,700 ft, comprises the producing reservoir. The original producing mechanism was that of an undersaturated solution-gas drive. Rapid pressure decline and the threat of climbing gas-oil ratios pointed toward the need for pressure maintenance. Performance to date under the influence of water injection has been very encouraging. During six years of water injection, the volumetric average reservoir pressure has increased 338 psi, from 1,583 to 1,921 psi. The producing gas-oil ratio has been reduced from about 1,300 to about 900 cu ft/bbl. Before water injection, it was necessary to withdraw approximately 2.3 reservoir bbl in order to place 1 bbl of oil in the stock tank. Now, 1 bbl of stock-tank oil requires a withdrawal of only 1.8 reservoir bbl. Peripheral portions of the reservoir which have experienced encroachment by the injected water have performed better than predicted. Based on this history and recovery predictions, ultimate recovery as a result of this water injection will be at least 50 per cent of the original oil in place. This is twice the predicted recovery without pressure maintenance. Introduction With the completion of Humble Oil and Refining Co.'s R. E. Bishop 1 (now known as Tract 35, Well 1) in March, 1949, the Sharon Ridge Canyon field was discovered. This field is located approximately 20 miles southwest of Snyder, Tex., and its Pennsylvanian reef reservoir was divided from the Kelly Snyder and Diamond "M" fields by means of arbitrary lines. In Nov., 1951, the Sharon Ridge Canyon field was combined with the Diamond "M" field. Less than two years after the discovery well had been completed and with the field only 75 per cent developed, the operators met and formed the "Sharon Ridge Canyon Engineering Committee". A great amount of work and study directed toward a conservation program resulted in the formation of the Sharon Ridge Canyon Unit, with 100 per cent of the operators signing the agreement. On May 1, 1955, unitized operations commenced with a peripheral water-injection pressure maintenance program. JPT P. 645^

Recurrent Asian influenza in an industrial population.

Article1 May 1961RECURRENT ASIAN INFLUENZA IN AN INDUSTRIAL POPULATIONNEILL K. WEAVER, M.D., F.A.C.P., JOHN G. LIONE, M.D., WILLIAM J. MOGABGAB, M.D., F.A.C.P.NEILL K. WEAVER, M.D., F.A.C.P.Search for more papers by this author, JOHN G. LIONE, M.D.Search for more papers by this author, WILLIAM J. MOGABGAB, M.D., F.A.C.P.Search for more papers by this authorAuthor, Article, and Disclosure Informationhttps://doi.org/10.7326/0003-4819-54-5-843 SectionsAboutPDF ToolsAdd to favoritesDownload CitationsTrack CitationsPermissions ShareFacebookTwitterLinkedInRedditEmail ExcerptAn epidemic of influenza may disable a significant number of workers in an industrial plant and seriously curtail its operation. At present, vaccination offers the only means of offsetting these consequences. Since acceptability of the vaccine dictates the amount of its use in a civilian population, this factor must be considered along with the protective effect of the vaccine in evaluating the degree of success in a program of control. Accordingly, it was of interest to investigate two occurrences of influenza A2 in an industrial population that had been offered influenza immunization on an annual basis since 1957.In the...Bibliography1. MogabgabPelonBurchHolmes WJWGEB: Characteristics of the Asian strain of influenza A. Proc. Soc. Exp. Biol. Med. 99: 116-20, Oct. 1958. CrossrefMedlineGoogle Scholar2. Mogabgab WJ, in Top, F. H.: Communicable and infectious diseases. C. V. Mosby Co., St. Louis, pp. 386-95, 1960. Google Scholar3. CareyDunnRobinsonJensenMartin DEFLRQKEJD: Community-wide epidemic of Asian strain influenza. J. A. M. A. 167: 1459-63, July 19, 1958. CrossrefMedlineGoogle Scholar4. DunnCareyCohenMartin FLDEAJD: Epidemiologic studies of Asian influenza in a Louisiana parish. Amer. J. Hyg. 70: 351-71, Nov. 1959. MedlineGoogle Scholar5. WalshBurchWhiteMogabgabDietlein JGEAWJL: A study of the effects of Type A (Asian strain) influenza on the cardiovascular system of man. Ann. Intern. Med. 49: 502-28, Sept. 1958. LinkGoogle Scholar6. GilbertCarawayBruceMogabgab VECTJMWJ: Epidemic recurrence of Asian influenza in Louisiana. 1959-1960. (To be published.) Google Scholar7. GriebleJacksonDowling HGGGHF: The etiology of common respiratory infections in a civilian adult population. Amer. J. Med. Sci. 235: 245-60, March 1958. 1958. CrossrefMedlineGoogle Scholar8. TrotterDunnDrachmanHendersonPizziLangmuir YFLRHDAMAD: Asian influenza in the United States, 1957-1958. Amer. J. Hyg. 70: 34-50, July 1959. MedlineGoogle Scholar9. Van GelderGreenspanDufresne DWFSNE: Influenza vaccination: comparison of intracutaneous and subcutaneous methods. U. S. Nav. Med. Bull. 47: 197-06, Jan.-Feb. 1947. MedlineGoogle Scholar10. PelonMogabgabDietleinBurchHolmes WWJLGEB: Antibody response to Asian influenza vaccination in man. Proc. Soc. Exp. Biol. Med. 99: 120-24, Oct. 1958. CrossrefMedlineGoogle Scholar11. McCarrollKilbourne JRED: Immunization with Asian-strain influenza vaccine: equivalence of the subcutaneous and intradermal routes. New Engl. J. Med. 259: 618-21, Sept. 25, 1958. CrossrefMedlineGoogle Scholar12. RendtorffWalkerRowlandPacher RCLCMEH: Intradermal immunization against Asian influenza in children. J. A. M. A. 170: 524-28, May 30, 1959. CrossrefMedlineGoogle Scholar13. EdwardsWellingsColwellKieneSigel HKFMFOIMM: Immunization against influenza in industry. Industr. Med. Surg. 27: 638-40, Dec. 1958. MedlineGoogle Scholar14. BogerAaronsonFrankel WPHGJW: Asian influenza: persistence of antibodies and revaccination. New Engl. J. Med. 262: 856-60, April 28, 1960. CrossrefMedlineGoogle Scholar15. LynchFoxThayerSchmit JMMWWRGL: Reactions to influenza vaccine inoculations. Arch. Industr. Health 21: 94-98, June, 1960. Google Scholar16. GreeneBeaver CCGT: A study of mass influenza inoculation in a large industry. J. Occup. Med. 2: 363-70, Aug. 1960. CrossrefMedlineGoogle Scholar17. GundelfingerStilleBell BFWTJA: Effectiveness of influenza vaccine during an epidemic of Asian influenza. New Engl. J. Med. 259: 1005-09, Nov. 20, 1958. CrossrefMedlineGoogle Scholar18. MogabgabHolmesBrightwellResler WJBRJCW: Effect of dosage and interval between injections on the antibody response to polyvalent influenza vaccine. (To be published.) Google Scholar19. BrownOligachlaegerLegierSchmidt GODMRR: Studies of the epidemiology of influenza as demonstrated by serum pools. II. Evidence of inapparent influenza infections and general level of population resistance as shown by the antihemagglutination reaction in serum pools collected by random sampling. Arch. Intern. Med. 106: 496-12, Oct. 1960. CrossrefGoogle Scholar This content is PDF only. To continue reading please click on the PDF icon. Author, Article, and Disclosure InformationAffiliations: *Received for publication January 1, 1961.From the Medical Department, Humble Oil and Refining Company, Baton Rouge Refinery, and the Department of Medicine, Tulane University School of Medicine, New Orleans, La.†Supported in part by U. S. Public Health Service Grant EP3509 to the Division of Infectious Disease, Department of Medicine, Tulane University School of Medicine.Requests for reprints should be addressed to Neill K. Weaver, M.D., Medical Department, Humble Oil and Refining Company, Baton Rouge Refinery, Post Office Box 551, Baton Rouge, La. PreviousarticleNextarticle Advertisement FiguresReferencesRelatedDetails Metrics Cited byPrevention of Acute Upper Respiratory DiseasesAcute Upper Respiratory Disease in IndustryPrinciples of active immunization for prevention of infectionAnnual influenza vaccination as a lifesaving measure 1 May 1961Volume 54, Issue 5Page: 843-855KeywordsEpidemiologyInfectious diseasesMedical servicesOilsVaccines ePublished: 1 December 2008 Issue Published: 1 May 1961 PDF downloadLoading ...

History of Humble Oil and Refining Company.

History of Humble Oil and Refining Company.

Determination of Fracture Orientation from Pressure Interference

Published in Petroleum Transactions, AIME, Volume 219, 1960, pages 301–304 Abstract Inclusion of anisotropic permeability in mathematical analysis of pressure transients observed during development of the huge Spraberry field indicates a major fracture trend which is in good agreement with that observed by fluid-injection tests spread over a 12- by 17-mile area. Delineation of this trend is important in selecting a pattern of injection for the pending large-scale water flooding in this field. Determination of reservoir parameters yielding best agreement between calculated pressures and observed reservoir pressures in newly completed wells was made using an IBM 650 computer. Introduction The Spraberry field covering 400,000 acres is a tight sand of less than 1-md permeability cut by an extensive system of vertical fractures. Primary recovery dominated by capillary retention of oil in the fractured sand matrix blocks is less than 10 per cent of oil in place. Strong forces of capillary imbibition of water into the sand, coupled with water flow under dynamic pressure gradient, indicate considerable increase in oil recovery can be achieved through water flooding. Best results will occur if the pattern of water injection is selected to force the water flow across the grain of the major fracture system. Existence of an oriented vertical fracture system in the Spraberry, observed first in cores, was highlighted more recently by the 144-fold contrast in permeability along and at right angles to the major fracture trend required to match relative water breakthrough times in Humble Oil and Refining Co.'s waterflood test there. Spraberry Operators since have conducted two gas-injection tracer tests for further areal confirmation of the fracture trend. Re-analysis of early reservoir pressure transients for evidence of anisotropic permeability has permitted many more local determinations of major fracture trend without resort to further field tests. This paper is limited to updating analysis of reservoir pressure transients to include anisotropic permeability as a test for orientation of the major fracture trend in the Spraberry. The reader is referred to Ref. 1 and 2 for information about general Spraberry reservoir performance and to Refs. 3 and 4 for information about significance of fracture orientation in selection of the injection well pattern for water flooding the Spraberry.

History of Humble Oil and Refining Company: A Study in Industrial Growth

History of Humble Oil and Refining Company: A Study in Industrial Growth

History of Humble Oil & Refining Company: A Study in Industrial Growth.

History of Humble Oil & Refining Company: A Study in Industrial Growth.

THE DYNAMICS OF A SUBMERGED MOORED SPHERE IN OSCILLATORY WAVES

The results of an analytical and experimental investigation into the dynamics of a buoyant sphere moored by a single line in shallow water waves are presented. The sphere motion and the mooring line forces are related to the sphere diameter, weight, submergence and the wave frequency, height and water depth. Analytically, the phenomenon is approached as a forced vibration problem. The sphere and its mooring line acts as a spring-mass system driven by the oscillating wave force. The relevant dimensionless parameters are the ratio between the natural frequency of the moored sphere and the wave frequency and the ratio between the dynamic mooring force due to a given wave and the force on the sphere held stationary in the same wave. Experimental values of the frequency and force ratios obtained from tests made at the Massachusetts Institute of Technology Hydrodynamics Laboratory over a range of sphere and wave characteristics are in essential agreement with the analytically determined values. The investigation was supported by the Humble Oil and Refining Company of Houston, Texas.

CLAY MINERALOGY OF MISSISSIPPI RIVER DELTAIC SEDIMENTS

Research Article| May 01, 1960 CLAY MINERALOGY OF MISSISSIPPI RIVER DELTAIC SEDIMENTS M. S TAGGART, JR.; M. S TAGGART, JR. PRODUCTION RESEARCH DIVISION, HUMBLE OIL & REFINING COMPANY, HOUSTON, TEXAS Search for other works by this author on: GSW Google Scholar A. D KAISER, JR. A. D KAISER, JR. PRODUCTION RESEARCH DIVISION, HUMBLE OIL & REFINING COMPANY, HOUSTON, TEXAS Search for other works by this author on: GSW Google Scholar Author and Article Information M. S TAGGART, JR. PRODUCTION RESEARCH DIVISION, HUMBLE OIL & REFINING COMPANY, HOUSTON, TEXAS A. D KAISER, JR. PRODUCTION RESEARCH DIVISION, HUMBLE OIL & REFINING COMPANY, HOUSTON, TEXAS Publisher: Geological Society of America Received: 24 Nov 1958 First Online: 02 Mar 2017 Online ISSN: 1943-2674 Print ISSN: 0016-7606 Copyright © 1960, The Geological Society of America, Inc. Copyright is not claimed on any material prepared by U.S. government employees within the scope of their employment. GSA Bulletin (1960) 71 (5): 521–530. https://doi.org/10.1130/0016-7606(1960)71[521:CMOMRD]2.0.CO;2 Article history Received: 24 Nov 1958 First Online: 02 Mar 2017 Cite View This Citation Add to Citation Manager Share Icon Share Facebook Twitter LinkedIn MailTo Tools Icon Tools Get Permissions Search Site Citation M. S TAGGART, A. D KAISER; CLAY MINERALOGY OF MISSISSIPPI RIVER DELTAIC SEDIMENTS. GSA Bulletin 1960;; 71 (5): 521–530. doi: https://doi.org/10.1130/0016-7606(1960)71[521:CMOMRD]2.0.CO;2 Download citation file: Ris (Zotero) Refmanager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex toolbar search Search Dropdown Menu toolbar search search input Search input auto suggest filter your search All ContentBy SocietyGSA Bulletin Search Advanced Search Abstract Late Quaternary Mississippi River deltaic sediments off the coast of Louisiana were studied to obtain information on possible clay-mineral alteration in a marine environment. The samples utilized were cores from four foundation test borings and included clays which had been deposited in several environments. For comparison, studies were also made of the clay minerals transported by the Mississippi and Red rivers.The results support the conclusion that clay minerals do not alter appreciably as a result of diagenesis in a marine environment and that the clay-mineral composition of source sediments determines the clay-mineral content of marine sedimentary rocks. All the deltaic samples contained montomorillonite, illite, kaolinite, and chlorite. The most noticeable variation among the samples was in montmorillonite content. Montmorillonite was the most abundant clay mineral in most of the deltaic samples but was much less concentrated in some of the remaining samples. Variations in montmorillonite content did not correspond with differences in depositional environment. Clays with high montmorillonite content occurred in both essentially marine and fresh-water facies.Analyses of samples of Mississippi River and Red River sediments indicated that these rivers carry the same suite of clay minerals as is present in deltaic sediments. Furthermore, samples of Red River sediment, characteristically reddish-brown, were predominantly low in montmorillonite content, whereas samples of the gray Mississippi River sediment were high in montmorillonite content. These differences in clay-mineral composition and color correlate substantially with corresponding variations in samples of deltaic sediment. This content is PDF only. Please click on the PDF icon to access. First Page Preview Close Modal You do not have access to this content, please speak to your institutional administrator if you feel you should have access.

Swisher Gabbroic Terrane of Texas Panhandle

Two wells recently completed in the Plainview basin of the Panhandle of Texas have yielded important geologic information concerning the age of the basement complex. A core from the Humble Oil and Refining Company9s Howard Ranch No. 1, Briscoe County, Texas, contained unmetamorphosed fossiliferous Paleozoic sediments intruded by diabase. This fact indicates that a part of the Swisher gabbroic terrane is younger than Precambrian. Another core, from the Humble Oil and Refining Company9s Reinauer No. 1, Deaf Smith County, Texas, was determined by the K-Ar method to have a minimum age of 650,000,000 years, or late Precambrian. A reexamination of all the wells drilled in the Swisher gabbroic terrane indicated that much of the gabbro is a diabase.

An Analysis of Large-Scale Flooding in the Fractured Spraberry Trend Area Reservoir

Introduction The Spraberry Trend oil reservoirs, producing from a very tight fractured sand, have been characterized by a rapid decline in reservoir pressure and oil producing rate and by production of only a small fraction of estimated original oil in place. Almost all original areas of development are now in the stripper stage or have been abandoned. Although it was considered unlikely that this solution gas-drive reservoir would lend itself readily to conventional methods of secondary recovery, a great deal of effort has been devoted to developing techniques which would utilize the unusual characteristics of the reservoir rock and its fracture system to increase ultimate oil recovery. A single five-spot pilot water flood was initiated in the west central portion of the Spraberry Trend Area reservoir during March, 1955. A combination analytical and numerical method employing high-speed computing equipment was utilized to analyze results of this pilot flood. With field behavior as the criterion for the analysis, orientation of the major fracture system, ratio of the permeability parallel and perpendicular to this trend, and relationship of the observed recovery from the center producing well of the pilot flood to that which might be achieved under large-scale flooding operations were determined. Information developed during analysis of the pilot water flood was then used to develop a flooding program for a 40-section area in the western portion of the field. From this work, it was concluded that the analysis procedure has considerable utility in analyzing flooding operations in a fractured reservoir and a relatively high pattern efficiency can be achieved in the area studied if the proper flooding pattern is chosen. Attempts to Develop Recovery Techniques The first attempt to develop a new recovery technique was a process designed by The Atlantic Refining Co. to utilize the principle of water imbibition. Laboratory work and the subsequent field trial demonstrated that water injected into the fractures could be imbibed spontaneously into the matrix rock by capillary action with the concurrent expulsion of oil into these same channels from which it could be produced by the surrounding wells. The second example of the research effort to increase oil recovery was work performed by Humble Oil and Refining Co. It was determined that with an intensive and inter-connected system of fractures, water injected into the formation could flood simultaneously a large number of matrix blocks. Water invading the matrix with the concurrent discharge of oil into the fractures would rapidly increase oil content and reduce water content of the effluent in the fractures moving toward the producing wells. To evaluate the potentialities of this type flood, a single five-spot pilot water flood was put into operation March 8, 1955.

Geologic Controls in Oil and Gas Exploration in Southwestern New Mexico and Southeastern Arizona: ABSTRACT

In southwestern New Mexico and southeastern Arizona the Paleozoic and Cretaceous sedimentary sections average between 15,000 and 20,000 feet in maximum thickness and consist largely of carbonate rocks. Humble Oil and Refining Company's recent well in southwestern New Mexico demonstrates the presence of oil stain and natural gas in the section. With such a thick sedimentary section and the known presence of oil and gas, the regional potentialities of commercial oil and gas are good. Successful exploration in the region depends largely on the discovery of sufficient porosity and favorable structural traps. Many stratigraphic units are consistent throughout the region and have low porosity, but others have regional differences, such as the presence of reefs, which favor higher porosity. Lower Cretaceous reefs in the region are distributed erratically, and neither reef trends nor the presence of reefs in the subsurface may be determined without intensive study. Lower Wolfcampian reefs, on the other hand, are more restricted stratigraphically and their trends may be determined. Since all other stratigraphic factors regarding favorable porosity are constant or at present are undetermined in the region, present exploration may best be concentrated in the belt where low r Wolfcampian reefs may be expected. The location of structural traps requires a fundamental understanding of the structural geology of the region. Two chief structural disturbances affected the region, an early one which in general is correlative with the Laramide orogeny and a later one which is correlative with the Basin-and-Range disturbance. Laramide structures include high-angle faults, large strong folds, and overthrust faults. Basin-and-Range structures include high-angle faults, broad gentle folds, and normal or block faults which produced the elevation of the ranges and the depression of the valleys. Basin-and-Range folds are so mild, compared with earlier strong Laramide folds, that their effect on pre-Tertiary rocks is negligible. Laramide anticlines, possibly in combination with later faults, supply the mo t favorable structural traps. As thick deposits of Tertiary volcanic rocks and of alluvium cover much of the area, the discovery of favorable structures must be based on projection of exposed folds under covered areas and on geophysical techniques. End_of_Article - Last_Page 1109------------

Fillmore Oil Field, Ventura County, California: ABSTRACT

The Fillmore field is a relatively minor Ventura basin oil field located west of and adjacent to the city of Fillmore. It is one of several recent discoveries in the Santa Clara Valley area between the Oak Ridge fault on the south and the San Cayetano fault on the north. The Fillmore field is an excellent example of multiple-zone primary stratigraphic trap accumulation, independent of local structural closure. Two middle Pico (Pliocene) sand zones have produced to date. Closure in both zones is effected by rather abrupt updip pinch-out on a low southeastward-dipping homocline. The Spalding pool was discovered by Standard Oil Company in April, 1954, and development of the field has been continuous and orderly since then. The Perkins pool, slightly shallower but more limited in areal extent, was discovered by Humble Oil and Refining Company in January, 1957. Both zones have short oil columns, small free gas caps, level water tables, and relatively narrow productive areas elongate essentially parallel with the regional northeasterly strike. At present the field is 3 miles long and has maximum width of 3,200 feet, with a proved productive area of approximately 800 acres. Average well depth is a little more than 14,000 feet, and gravity of the oil is 27°-35° API. Cumulative production to August 1, 1957, was 2,387,000 barrels, and average production as of that date was 7,984 B/D from 22 wells. The productive limits of the two known pools have been fairly well established except at the east end of the field, where development is continuing at present. Future expansion of the field depends on its easterly extent and possible discovery of additional Pliocene sand pinch-out traps. End_of_Article - Last_Page 216------------

Developments in Alaska in 1957

The Territory of Alaska comprises more than 600,000 sq. mi. Increasing interest in the northern and central provinces as well as the southern province developed in 1957. The northern province, including the Arctic coastal plain, has been withheld from public entry as Naval Petroleum Reserve No. 4 and by Public Land Order No. 82. The U.S. Department of the Interior has recently announced lands withheld under P.L.O. No. 82 will be opened in 1958. The central province including the Porcupine, Koyukuk, Bethel, and Nushagak regions is in a very early stage of exploration. Acreage leased in these regions by the end of 1957 probably exceeds 10 million acres. Surface geological investigations during 1957 totaled 21 party-months and seismic and magnetometer surveys 6 party-months. The southern Alaska province includes the Copper River, Cook Inlet, Alaska Peninsula, and St. Elias-Coastal regions. Drilling activity increased 4-fold in 1957 over 1956. The total footage drilled in 1957 was 52,480 ft. as compared with 15,168 ft. in 1956. Drilling in the Cook Inlet basin resulted in a major discovery that may develop into the first substantial commercial production in Alaska. In the Copper River basin no new activity except leasing took place in 1957. Total filings in the basin were approximately 2 million acres. In the Cook Inlet basin the Richfield Oil Corporation's Swanson River Unit No. 1 was completed for 900 b/d from 11,150 to 11,215 ft. in Tertiary sands. The well was located on the basis of seismic and surface data and is the first deep test in the basin. Following the discovery, competitive lease activity ensued and leases or applications to lease cover the basin. In the St. Elias-Coastal region the Phillips Petroleum Company and Kerr-McGee Oil Industries, Inc. abandoned their Sullivan No. 2 as a dry hole at 12,048 ft. and terminated their development contract with the U. S. Department of the Interior. The Colorado Oil and Gas Corporation abandoned its Yakutat No. 1 at 9,314 ft. and at the end of the year was drilling ahead at about 10,500 ft. on its Yakutat No. A-1. Nearly all of the accessible land in this region was leased or under application. In the Alaska Peninsula region Iniskin Unit Operator, Inc. tested its Beal No. 1, total depth 9,746 ft., and received oil and gas indications. The Humble Oil and Refining Company and Shell Oil Company's Bear Creek Unit No. 1 was drilling at 6,586 ft. at the end of the year. About 3 million acres were leased or under application in the region. Exploration in Alaska is expected to increase sharply in 1958 over 1957.

An Electronic Analog Cross Correlator for Dip Logs

The Dip-Log Correlator is a special purpose electronic analog computer which rapidly cross correlates the three variable functions of a dip-meter well log. This cross correlator utilizes a novel derivation and application of the cross-correlation function from information theory. A prerequisite of the system is the recording of the dip-meter data on magnetic tape for computation by the cross correlator. The triple cross-correlation technique and some of the essential circuitry of the cross correlator which is in operation as a geophysical tool at the Humble Oil & Refining Company Houston Research Center are described.

Humble Oil Company Radiocarbon Dates I

Humble Oil Company Radiocarbon Dates I

High Temperature Sulfide Corrosion In Catalytic Reforming of Light Naphthas★,—A Contribution to the Work of NACE Task Group T-5B-2 on Sulfide Corrosion at High Temperatures and Pressures in the Petroleum Industry from Humble Oil and Refining Co., Baytown, Texas*

Abstract When a catalytic reformer at Humble Oil & Refining Company's Baytown, Texas plant showed alarming pressure drop across the reactors after about 50 days' operation principally as a result of plugging with iron sulfide scale, immediate steps were taken to investigate the source of scale and the importance of metal losses occurring in the system. Over 600 pounds of iron dust was removed from the reactor and the unit put back in operation. In a month's time it was necessary to screen the catalyst again. Heavy scale was found in the first exchanger on the reactor effluent stream both from the tubes and deposited from piping upstream. Catalyst was channeled and plugged. When it became apparent the scaling was the result of sulfide attack and possibly severe corrosion in the furnace tubes and other components a testing program was begun. Several materials were tested at various locations in the stream by the electrical resistance method. Hydrogen sulfide content of the naphtha charge and recycle gas was determined. Corrosion rates during operation on heavy naphtha varied from 0.15 to 0.4-inch on carbon steel and chrome alloys but the rate on 18-8 was about one-tenth that of the other metals. Chromium alloys through 12 percent in many instances showed corrosion rates higher than those of carbon steels. In a laboratory pilot unit, tests indicated that aluminized steel generally showed good resistance and that hydrogen sulfide concentrations under 0.008 mol percent did not cause appreciable damage at temperatures about 1000 F. Humble plans to install a hydrofining unit to reduce sulfur content of the naphtha to about 40 ppm before it is charged to the naphtha reforming process. 3.2.2