bluuebunny/crossref_metadata_2025_split huggingface dataset:
Abstraction of Sulfonates and Dodecane by Alumina
Authors: Viswanathan K. V. , Somasundaran P. 
Published: December 2007

ABSTRACT
Investigation of the effect of oil on the adsorption of surfactants on reservoir rock minerals as well as the uptake of oil by the solid in the presence of surfactant is important for micellar flooding recovery systems. In the present study, the effect of oil on the adsorption of isomerically pure n-Na dodecylbenzene-sulfonate and n-Na decylbenzenesulfonate on alumina and the uptake of oil by the solid were determined as a function of surfactant concentration, ionic strength and temperature.
While the oil was found not to affect the sulfonate adsorption appreciably under experimental conditions studied, the uptake of oil as a function of sulfonate exhibited a decrease and in some cases followed by an increase. The results are discussed in terms of surfactant micellization and salting out, co-adsorption of oil at the solid/liquid interface and the solubilization of oil in micelle.
Oil Shale And Shale Oil
Authors: Crabtree E.H. 
Published: December 2007

There has been so much written and there have been so many addresses and technical presentations on oil shale given at various meetings during the last few months that it is difficult to present anything new. Even to summarize the history, the current status, the problems, and the potential of the industry would require much more time than we have today. So about all I can hope to do is to present some of the highlights, knowing that some of these will be a repetition for many of you, but hoping that I can give you members of the mining industry a perspective of what the oil shale industry is today and where it will probably be tomorrow.
For us who have spent our professional lives in the mining industry, oil shale is unique. We know where it is; we don't have to hunt for it. It is measured in hundreds of feet of thickness, in thousands of square miles of area, and in billions of barrels of oil content. The problems are technological and legal. How will be the best way to mine the shale? How will be the best way to extract the oil? Where will it be marketed? What will it cost? What will be the leasing and tax policies of both the State and Federal governments?
One of the many questions asked today is why do we need shale oil? With a large portion of our domestic crude production restricted, and with limitations on imports from large foreign sources, won't we have all the conventional petroleum required? The answers to these questions are more questions. Can we afford to be dependent upon foreign supplies? Are our domestic reserves sufficient for our expanding needs? Will the cost of finding new reserves eventually exceed the cost of producing shale oil?
Recently, Assistant Secretary of the Interior John Kelly quoted President Johnson as follows: ". . . In the remainder of this century urban population will double, city land will double, and we will have to build homes, highways, and facilities equal to all those-built since this country was first settled. So in the next 40 years, we must rebuild the entire urban United States."
If this is true, a tremendous increase in sources of energy will, of course, be required. With our present reserves of petroleum and coal, and atomic energy being rapidly developed, no shortage is anticipated.
The Dissolution Effects of CO2-Brine Systems on the Permeability of U.K. and North Sea Calcareous Sandstones
Authors: Ross Graham D. , Todd Adrian C. , Tweedie John A. , Will Andrew G. S. 
Published: December 2007

ABSTRACT
Dissolution could be a serious problem in the operation of a carbon dioxide flood on a carbonate cemented sandstone. Laboratory core flooding experiments under reservoir conditions demonstrate the effect of the dissolution and the significance of textural properties of the rock. Core flood tests carried out on North Sea core material show similar permeability alteration and effluent concentrations both as a result of channelling and of total dissolution. The presence of residual oil delays the dissolution process. The textural heterogeneity in real rocks make it difficult for existing acidization models to be applied to the interpretation of the laboratory results.
Modeling of Gas Injection in Fractured Reservoirs
Authors: Eica Aniefiok Sunday , Ershaghi Iraj 
Published: December 2007

ABSTRACTGas injection into a naturally fractured reservoir is simulated using a mathematical model which includes convective and capillary forces. The study conducted for both a single matrix block and a stack of matrix blocks shows that recovery of oil from low permeability matrix can be optimized by commencement of gas injection early in the productive life of the reservoir. Furthermore, by manipulating the pressure distribution in the system through temporarily shutting in the production wells when GOR's are high, the ultimate oil extraction from the matrix blocks may be improved.
Quality Assurance — No Margin for Error
Authors: Thomas R. L. , Smith C. F. , Grant W. D. 
Published: December 2007

ABSTRACT
Quality Assurance (QA), a critical component of a hydraulic fracturing treatment, must be performed prior to and during the job. Failure to follow QA procedures may result in added well costs and poor production. It begins during the design and ends after the completion of the job. The importance of Quality Assurance has been magnified in recent years due to the increased size and complexity of fracturing treatments. It is a tool used to ensure that fluids, proppants and equipment meet the increased demands placed upon them.
This paper discusses several steps taken in order to provide Quality Assurance. An explanation of procedures used during the job design and prior to the job is given. A discussion of procedures and troubleshooting techniques used prior to and during the job is also presented. The sensors and computer system used in order to monitor QA data are also discussed.
Bottom-Hole Stresses in a Well Bore
Authors: Deily F.H. , Durelli A.J. 
Published: December 2007

Abstract
Bottom-hole stresses in a well bore have been calculated using the results of photoelastic analyses. Boreholes in the earth were simulated in marblette cylinders. Three hole bottom contours were studied, including flat and semi-hemispherical bottoms. Two types of surface stresses were found at or near the hole bottom, meridional and circumferential. Stress concentration factors are presented graphically as a function of overburden (geostatic) and well bore (hydrostatic) pressures. For well bore and overburden pressures encountered in normal mud drilling, radial stresses on a flat bottom hole may change from 74 per cent of overburden at the center to 192 per cent near the hole wall. Knowledge of triaxial states of stress across the hole bottom will enable a better understanding of rock strength under borehole conditions.
The purpose of this study is to determine bottom hole rock stresses in terms of overburden pressure and borehole pressure. The knowledge of such stresses will enable better future prediction of rock strength and drilling action.
Since hole end geometry is complex, serious mathematical difficulties are encountered in solving this problem. Consequently, the use of three dimensional photoelastic techniques was chosen to achieve these objectives. Of primary concern in the photoelastic study was the determination of the two principal stresses in a plane tangent to the surface of pressurized boreholes. Principal stresses act on planes in which no shear exists.
Petroleum Engineering Manpower Supply
Authors: Dorfman Myron H. , Harkins H. B. (Burt) 
Published: December 2007

Abstract
The supply of Petroleum Engineers within the U. S. has shown an exponential growth during the last decade due to increases in the price of petroleum and concommitant demand for engineers in the petroleum industry at all levels of activity. Schools currently have very large enrollments; many lack sufficient faculty and facilities to adequately handle the large loads. Recent uncertainty in long range forecasting of petroleum demand, coupled with uncertainty in the price of oil due to turmoil in the Middle East and the discovery of additional large reserves of petroleum as a result of increased drilling, has led to a decline of approximately 25% in the price of crude oil on the spot market and subsequent reductions in drilling in 1982 from a high of 4,500 rigs in the U. S. to 2528 rigs by August 31, 1982; a reduction of 44% this year. This reduction in activity will be reflected in reduced job opportunities for many new graduates in December 1982 and in 1983, and the "pipelines" within the schools are filled with students in expectation of good jobs in the private sector of the economy. Since Petroleum Engineering departments maintain a close tie with industry, it is essential that some balance be maintained between supply and demand, so as to try to prevent a glut of engineers descending upon the market. Steps are underway at many schools to reduce enrollments by a variety of methods at the present time. An upturn in demand in petroleum prices may serve to mitigate the problem within the next two years, but a long-range interchange between industrial hiring forecasts and universities is essential in planning for the future.
The Field Development of Cognac (Mississippi Canyon 194) Field: A Case History
Authors: Nations J. F. , Speice C. B. 
Published: December 2007

ABSTRACT
The drilling operations portion of the field development of Project COGNAC (Mississippi Canyon Block 194 Field) was completed in August, 1981, six months ahead of schedule. Activities conducted during the "drilling cycle" included drilling and casing 61 wells and completing 36 wells for production before rig down. The wells developed a four-block, multizone accumulation from a dual rig platform set in a world record 1025 feet of water.
The case history of the field development of COGNAC documents the geological and drilling planning/experience unique to a project that included: Two drilling rigs operating simultaneously yet independently from one platform;Potential problems associated with shallow wellbore interference. Accidental well intersections were avoided despite a high interference potential;High angle/long reach wells. Thirty-four (34) of the 61 wells had average drift angles in excess of 50°. Wellbore drifts up to 7850 and 9790 feet at true vertical depths of 7922 and 8660 feet respectively were accomplished and casing run to total depth; andSimultaneous producing while drilling (PWD) operations. Oil production from the platform began approximately two years before the end of drilling activities.
The planning and experience summarized in the paper should be valuable to Geological and Drilling Engineers involved in development planning of fields located in the offshore environs.
Economic Considerations Affecting Steam Flood Prospects
Authors: Keplinger C.H. 
Published: December 2007

Steam stimulation results have been given "glamorous" coverage in the oil and financial press in recent months. One article spoke of steam injection as a "tonic" for tired oil fields, a "thermal Geritol" which thins down viscous crude and helps stimulate the production of oil. Some isolated spectacular results have indicated very large initial increases in production.
An attempt has been made to collect well performance data of steam soak operations for economic appraisal. Twelve operators were contacted and I am grateful and appreciative of their cooperation. Not all those contacted furnished data, but they were helpful in their encouragement to prepare the paper. Some producers have kept their steam injection operations quiet while learning the technology of steam stimulation. However, for this paper, the operators who made available their stimulation results furnished well performance data of the heavy oil fields of the San Joaquin Valley of California. The attached map, Plate I, shows the location of thermal steam projects in California together with the names of the operators in each field.
In evaluating the economics of steam "soak" recovery, there is no escaping the uncertain task of peering into the future based on available past performance. A detailed forecast is a massive job and falls outside the scope of this paper because much of the available data on performance has not been released by operators; nevertheless, it is intended to treat the subject in the broadest of terms with the limited operational data in order to identify the main economic considerations.
Successful operations are dependent on initial and repeated productive response to steam injection, productive trends after each steam soak, optimum spacing and steam costs.
At this time steam flooding will be briefly described and defined. There are three primary methods of using steam to increase oil production. Plate II shows these three induced production methods by steam injection.
Filtration of Gas on Offshore Platforms With Special Reference to Sand Removal and Slug Catching
Authors: Forsyth Donald F. , Chamberlain Neville P. 
Published: December 2007

ABSTRACT
Multicyclone designs have proved effective in reducing the cost and weight of high pressure gas wellhead separators. This is achieved with improved efficiency and turndown range over other types of separators. Erosion problems and their solution are discussed.
Similar savings in size and weight with improved efficiency and turndown are also being achieved in offshore slug catching separators.
Modified In-Situ Retorting Results of Two Field Retorts
Authors: Berry Kay L. , Hutson Roy L. , Sterrett John S. , Knepper Jay C. 
Published: December 2007

ABSTRACT
Rio Blanco Oil Shale Company (RBOSC) has designed, constructed and processed two Modified In Situ (MIS) retorts at Tract C-a using newly developed techniques for rubbling, ignition and operation through surface drill holes. Retort Zero was ignited in October 1980, nominal dimensions 30' × 30' × 165' (9 × 9 × 50 meters), oil yield was 1,876 barrels (298,300 liters). Retort One was ignited June 1981, nominal dimensions 60' × 60' × 400' (18 × 18 × 122 meters), oil yield was 24,444 barrels (3,886,000 liters). RBOSC's MIS method was proved very successful; ignition was achieved in less than 36 hours, average front advance rates were 2.7 and 3.0 ft/day (.8 and .9 meter/day) and oil yields were 68 percent of Fischer Assay, close to model predictions for both retorts. This paper will describe conceptually the MIS method developed by RBOSC and give the process results. Details of how the results were achieved are proprietary.
Cycles of Crisist, Seasons of Glutt … Wheret Do He Go From Here?
Authors: Lee James E. 
Published: December 2007

Abstract
From Maine to Texas, there are a couple of cliches you'll hear if you ask about the weather. One of them goes, "If you don't like the weather around here, just wait a little while, and it will surely change."
It strikes me that much the same thing might be said about market and supply conditions in the oil business.
Just think, for example, of the extraordinary changes in the oil market over the recent past. only a few years ago, the national scene was characterized by shortages and rumors of shortages, by vaulting prices and plunging spirits … amd by presidential lectures about a new french import called "malaise".
The United States Petroleum Industry Investment and Capital Markets Outlook : A Chase Perspective
Authors: Carey James H. 
Published: December 2007

Abstract
Good afternoon, ladies and gentlemen.
I'm particularly pleased to be with you today -- and not only because it is an honor to speak to such a pivotal group of professionals in what is clearly one of the world's most essential industries.
Before discussing the present and future funding of the U.S. petroleum industry, I want to define briefly for you the economic environment in which we believe the industry will be operating through the balance of the decade.
A Method for Selecting Potential Infill Locations in the East Texas Cotton Valley Tight Gas Play
Authors: Tison Joel K. , Agarwal Ram G. , Rosepiler Michael J. , Schlottman Bernard W. 
Published: December 2007

ABSTRACT
To fully develop producing acreage in low permeability gas plays, infill reserves must be assessed and development areas must then be identified. Currently in Texas, at least 25 major tight gas plays have been recommended for tight gas formation designation to the Federal Energy Regulatory Commission, and at least 10 of these have been approved for incentive gas pricing. In the East Texas Basin alone, there are at least 10 major field areas in a tight gas sand play. All of these plays and fields within them will require study to determine the feasibility of infill development. A technique for selecting potential infill locations is outlined below.
Critical reservoir and fracture parameters are investigated by determining each parameter's effect on the incremental reserves from an infill well. The most important parameters are: formation flow capacity, hydrocarbon pore volume, fracture length, and pay continuity.
These parameters are used to obtain simulated rate data for well groups from a tight gas reservoir simulator. Recoverable gas is determined from a plot of the simulated data as scalar curves relating well rate and cumulative production data to time, normalizing the curves to the above critical parameters. Potential infill reserves are assessed for East Texas Cotton Valley wells using the results from the above curves in an expression for incremental infill reserves. The variation of incremental reserves with fracture length for varying permeabilities is investigated to obtain an economic limit on incremental reserves for a general area and to determine the range of permeabilities justifying reduced well spacing.
This two-well analysis approach assumes separate, non-interfering drainage blocks and may introduce error in high permeability areas. Moreover, this analysis technique assumes no time delay in drilling the infill well on a unit. Static pressure measurements in the first infill wells must be obtained to evaluate potential interference as well as gain experience in drainage radii for the original wells on a unit.
Onsite Analysis of Sucker Rod Pumping Wells
Authors: Kramer M. J. C. , Martin J. D. , Neely A. B. 
Published: December 2007

ABSTRACT
Shell Oil Company has developed a van-mounted minicomputer system that determines surface and downhole rod pumping performance at the well site using the Sucker Rod Diagnostic Technique. The benefits achieved, the reliability of both the hardware and software, and the number of systems placed in operation have far exceeded expectations. The system has proved to be a significant factor in the operation of Shell's rod pumping wells, as well as an effective training tool for both Engineering and Operations.
Field Testing the Fluid Rod Production System
Authors: Peterson Daniel G. , Brady Joseph 
Published: December 2007

ABSTRACT
The Fluid Rod Production System introduces a new concept for the production of low volume wells. Utilizing production fluid or non-treated lease water as the power transfer medium, fluid power is transmitted from a skid mounted surface unit to a downhole stroker which directly actuates a standard API rod type pump.
This Fluid power is cyclicly applied and relieved at the surface unit to create a pumping action downhole. The fluid utilized for power transfer is contained in a small diameter tubing string and with the exception of a small amount of slippage downhole, remains in this string thus eliminating the need for a large fluid supply or fluid storage and treating facility.
Field testing now underway has demonstrated that the Fluid Rod Pump is a viable alternative for the production of low volume wells. Prototype system testing has been under way in Brea, California since October of 1981.
During that time the system has been tested at various production rates up to 155 BFPD and the optimization of components has been carried out. A production version of the system has been operating in Wilmington, California since June of 1982. This installation has demonstrated the versatility of the system by operating at an average of 20 BFPD in a well deviated 19° from vertical at the seating depth.
Surface Detection of Retort Gases from an Underground Coal Gasification Reactor in Steeply Dipping Beds Near Rawlins, Wyoming
Authors: Jones Victor T. , Thune Howard W. 
Published: December 2007

Abstract
A near-surface soil-gas geochemical survey was executed in conjunction with the Phase II experiment at the North Knobs, Wyoming, GR&DC-DOE UCG facility from July 22, 1981, through December 12, 1981.
The soil-gas detection method offers a unique new technique for locating potential gas leakage areas before any significant migration avenues can develop. This approach has the advantage over atmospheric measurements because the soil gases are not greatly affected by winds and other varying meteorological conditions; therefore a much lower level anomaly may be resolved.
One hundred and twenty-two, 18 foot deep permanent sites, based upon the local geology, were located and installed over the areas of both the previous Phase I and the current Phase II retorts. All sites were routinely monitored for methane, ethane, propane, i-butane, n-butane, ethylene, propylene, helium, hydrogen, carbon dioxide and carbon monoxide. Selected sites were periodically monitored for carbon disulphide, carbonyl sulphide, hydrogen sulphide and sulphur dioxide.
The survey demonstrates that residual gases from the Phase I burn are still present in the near surface and product gases generated during the Phase II burn were clearly evident. Maps are presented showing the areal distribution of these products during: (1) the pre-burn, pre-pressure period; (2) the air-pressured interval during system checkout; (3) the ignition and early burn period; and (4) the late-burn and early post-burn interval. These maps and the tabulated data indicate a recognizable surface response occurred 3-6 days after changes in the burn retort pressures. Product gases migrated into the near surface both vertically and laterally along well developed cross-joints and near-strike joint sets within the sandstones stratigraphically above the coal seam being burned. Additional leakage is probably associated with poor cementing of the casing in some of the deep boreholes. Casing leakage explains most of those anomalies located in the rock sequence stratigraphically below the coal. While throughout the survey abnormally high values were found in the near surface at many geochemical sites, ambient air samples routinely taken near those sites consistently had low values. It is concluded that a properly designed and operated UCG facility would not experience any adverse product gas leakage and would pose no hazard problems from either a safety or environmental point of view.
Fracture Orientation Analysis by the Solid Earth Tidal Strain Method
Authors: Hansont Jonathan M. , Owen Lawrence B. 
Published: December 2007

ABSTRACTA new practical method has been developed to estimate subsurface fracture orientation based on an analysis of solid earth tidal strains. The tidal strain fracture orientation technique is a passive method which has no depth limitation. The orientation of either natural or hydraulically stimulated fractures can be measured using either new or "old" static observation wells. Estimates for total compressibility and areal interconnected porosity can also be developed for reservoirs with matrix permeability using a combination of tidal and barometric strain analysis. Data acquisition requirements are modest and no surface instrumentation beyond pressure monitoring equipment is required. The tidal method has been successfully demonstrated at a naturally fractured geothermal field (Raft River) in Southeastern Idaho and at an oil field in Western Canada. Both case studies are described.