bluuebunny/crossref_metadata_2025_split huggingface dataset:
Unique Simulation Development Enhances Operation of Downhole Well Test Tools
Authors: Schwendemann Ken , Beck Kent 
Published: December 2007

Abstract
Oilfield technology has experienced such rapid advancement during the last decade that end users often find themselves lacking in the ability to understand and properly use the newly designed equipment; thus, they are unable to take full advantage of the benefits that the enhanced systems offer.
This paper will discuss the development of a new simulator that solves this problem by providing the oilfield end user with on-line ability to understand and properly operate newly designed equipment.
The simulator uses a very natural graphical user interface to convey complex technical information, and its usage enables a broader range of developers to produce quality simulations that would previously have been limited to development by the expert programmer.
In addition to a discussion of the development of equipment simulator methodology, the many uses of the technology that have been identified to date will also be presented. These include: Conveying complex technical informationReducing personnel training timesDesigning well testsReviewing design processes to verify design parametersVerifying customer requirementsAllowing operators to "practice" the well test before it is applied
The use of the equipment simulator promotes better understanding of equipment used for servicing and operation of the rig and well. With overall goals depending upon reductions in costs of drilling and completing wells, a better understanding of equipment helps ensure safer, more efficient operating conditions, which in turn, increases the probability for realization of economic goals.
Well Test Analysis by Reservoir Simulation Coupled with a History Matching Program
Authors: Hwan R. Randy 
Published: December 2007

Abstract
A procedure of well test analysis using a reservoir simulation model coupled with a history matching program has been developed, The history matching program used in this study is called "Adaptive History Matching (AHM) System" which was developed by Scientific-Software Intercomp (SSI) with the participation of Texaco and two other major oil companies. AHM was designed to help the engineer deal with the problems of history matching reservoir performance data with a reservoir simulator. Pressure data measured in well test is directly history matched with the current method without converting to dimensionless terms or taking the logarithm of the data.
The history matching system used in the current procedure is based on Bayesian inference. Bayes’ theorem provides a process of learning from experience and shows how knowledge about the state of nature can continually be modified as new data becomes available. Four cases of well test analysis are presented in this paper. They include a single well test, an interference well test, a multi-layered reservoir case, and a horizontal well test. In each case, the conventional well test results are included for comparison with those of the current method. It only requires a few simulation runs for the current procedure to obtain the well test results.
The interference case shows that the pressure data of the observation well during injection and shut-in periods at an active well are matched by the current method, The analyses by conventional methods can only be conducted during either the build-up or the shut-in period. In the multi-layered case, with crossflow at the wellbore between the high and low permeability layers, the current method is capable of determining the permeabilities of these layers individually. In contrast, the conventional well test analysis only provides a composite permeability value for a multi-layered reservoir. The current procedure is also applied to the horizontal well test analysis. The horizontal and vertical permeabilities are analyzed simultaneously.
Pollution Problems in the "Oil Patch"
Authors: Rold John W. 
Published: December 2007

Abstract
Throughout much of the "oil patch," water truly exemplifies the economic, sociologic, political and ecological lifeblood of the community. The permanent supply of usable water, on which the arid West depends for survival, faces many hazards. Currently, much available water exceeds or is rapidly approaching Public Health limits, and the tolerance level of the inhabitants.
Water enters an area as river flow or rainfall. It goes underground by natural seepage or irrigation where it percolates until it surfaces at natural springs or wells (domestic, irrigation - municipal or industrial) to re-enter surface flows. Normally, the cycle is repeated many times. Each cycle degrades the water quality. Although oil field operations contribute a small proportion to total degradation of the hydrologic system, each incident of oil field pollution is specific and highly newsworthy. When attempts to clean-up waters are made, the oil industry provides the first and most vulnerable target. Oil field practices can and do pollute water, mainly by increasing total dissolved solids (principally chlorides and sulfates), but also by releasing crude oil.
Ground water pollution is often difficult to prove and may not appear immediately. Conversely, its effects may persist for many years. Pollution may occur from:
Evaporation Pits. Regardless of the concentration of brine entering a pit, the only substance leaving the pit by evaporation is pure distilled water vapor. Everything else remains behind forever or enters the water system either by seepage through the bottom of the pit or overflow. In Colorado during 1969, 27,000,000 barrels of water (1,110 to 35,000 ppm salinity) went to unlined pits. A 1966 detailed study of a ground water basin in NE Colorado showed that one small brine pit contributed a 27 ppm per year salinity increase to the entire ground water basin. Insufficient surface casing. Any surface casing which is not set below, and does not seal off all fresh water aquifers constitutes a pollution hazard. Any injection system. Waste disposal or water floods constitute a hazard; not only from casing leaks but also from cross-formational flows through natural or induced fractures.
The Application of Petroleum Engineering Science And Technology to Subsurface Disposal of Liquid Industrial Wastes
Authors: Donaldson Erle C. , Johansen Robert T. 
Published: December 2007

Abstract
The direct application of oilfield technology to subsurface disposal of industrial wastes has directed attention to numerous technical problems. These arise because of (a) the special design and operation required for wells intended for disposal of highly corrosive fluids, such as pickle liquor, from steel companies; (b) special precautions that must be taken to avoid injection of an immiscible phase with the aqueous waste (a small percentage phase with the aqueous waste (a small percentage saturation of an immiscible fluid in the disposal formation will seriously decrease the relative permeability to water); (c) special treatment of the formation and waste when swelling clay is present in the disposal formation; and (d) the limiting volume of some formations. Some of these problems encountered by chemical industries are described.

Introduction
Subsurface disposal of liquid waste has been practiced by the petroleum industry since about 1920 when it was applied to oilfield brines. Currently the U.S. oil industry injects about 17 million B/D into subsurface formations. In contrast, a survey of liquid waste injection by the chemical industry, made in 1962 by the U.S. Bureau of Mines, showed that 32 wells were being used to inject 136,000 B/D of industrial waste. Estimates from recent national survey, indicate that about 150 wells are being used to inject approximately 675,000 B/D of industrial wastes into geologic formations ranging in depth from 1,000 to 8,000 ft. Thus, in 8 years the volume of industrial waste injected underground has increased five times.
The successful injection of waste by the chemical process industry shows that subsurface waste disposal offers a solution to extremely difficult liquid waste disposal problems. Concentrated acid wastes, caustics, problems. Concentrated acid wastes, caustics, solutions of salts, organic phosphates, phenols, chlorinated hydrocarbons and mixed organic and inorganic wastes are being disposed of economically by injection into geologic formations.
There are many advantages of subsurface over surface methods of waste disposal. Capital investment and operating costs are lower, the surface area required for the plant is less, seasonal temperature variations plant is less, seasonal temperature variations have less effect on the system, chemical treatment of the waste is minimal, and generally the only physical treatment required is filtration.
Dynamic Effects of Foamy Fluid Flow in Sand Production Instability
Authors: Geilikman M. B. , Dusseault M. B. , Dullien F. A. L. 
Published: December 2007

Abstract
As a major component in the development of better flow models for the "cold production" process in heavy oils, formation of a foamy fluid phase during flow of a liquid containing dissolved gas toward a wellbore is considered. The appearance of gas bubbles in the flowing fluid is described by the theory of nucleation. Unlike previous approaches, the foamy state is interpreted as a metastable state which starts developing at pressures below the bubble-point of a gas-fluid phase diagram. The amount of gaseous phase is determined kinetically, that is, by the rate of nucleation. Mass balance analysis for the compound foamy fluid gives the spatio-temporal evolution of the foamy zone which starts growing around the wellbore. Fluid pressure in the foamy zone exhibits a steeper gradient, compared to the non-foamy flow. The conditions of sand production instability via tensile failure at the foamy front are also determined, and this constitutes a condition for liquefaction and loss of effective stress in the granular medium.
Study on Technology of Mixing Active Water in Shanjiasi Heavy Oil to Reduce Viscosity
Authors: Chen Shen , Lijie Yuan 
Published: December 2007

Abstract
The study present in this paper aims to solve the problems happening in the heavy oil production wells with steam stimulation in Shanjiasi, Shengli Oilfield, that at the end of a circle, temperature fall causes the viscosity of the production liquids to increase significantly, which leads to various accidents. By analyzing the. laboratory test of the viscosity reduction and rheology of the heavy oil, etc., the feasible mechanism of mixing active water in heavy oil to emulsify and the relevant downhole prodution technique are obtained. With the technology of injecting active water down the annulus in three wells, the stable production is insured in the late production period of heavy oil wells with steam injection, and the production period is prolonged with a favorable economics.
Benchmarking Heavy Oil Operations - A Step to Improved Profitability
Authors: Sonmor Randell G. 
Published: December 2007

Abstract
This paper discusses the application of benchmarking to Heavy Oil operations in Western Canada. Benchmarking is used in many industries to compare performance among competitors. Benchmarking can enhance a company's competitive position which can lead to increased profitability and added value for the shareholders. The Ziff Energy Group, using its ten years of benchmarking the Western Canadian Exploration and Producing Industry, prepared an in-depth Heavy Oil Benchmarking Study with the participation of key Western Canadian heavy oil producers. The study covered the period January 1 to September 30, 1993. The report focused on benchmarking the main cost categories of "operating costs" for approximately 140 heavy oil fields. The classifications Included; well servicing, repairs and maintenance, property taxes and lease rentals, fuel and utilities, contract services, labour, emulsion trucking, sand disposal, and miscellaneous. Given the diversity in oil quality, reservoir characteristics, and royalty regimes in Western Canada the fields were benchmarked for each of the four main heavy oil producing regions: (1) Western Saskatchewan (2) East-Central Alberta (3) Cold Lake and (4) Southeastern Alberta. The study provides the producer with a practical tool to compare it's operating costs with competitors’ costs in the same geographic area. Such comparison can be valuable in developing plans to lower costs and increase profitability.
New Technology of Heavy Oil Profitability Increasing
Authors: Belonin M. D. , Gribkov V. V. 
Published: December 2007

Abstract
The offering method of development of the high-viscous oil fields foresees the territorial and technological combination (TTC) of production and refining of them. It permits, on the basis of new technology, to carry out the closed process - from receipt of raw, as producing oil, to production of the finished products. Simultaneously, the heavy fractions of refining oil and smoke gases from a refinery plant are injected in a reservoir for combined impact to it.
Application of this technology can provide:
– oil recovery coefficient - 0,5 and more, – degree of oil refining - 80 % and more, – increasing of ecological indices in 10 times and more in comparison with traditional technologies, – increasing of economical efficiency of oil production and refining in 2 times and more, – recovery of associated useful components (sulfur, vanadium, nickel, gypsum etc.) as commercial products.
Treatability of Refinery and Petrochemical Wastes
Authors: Carnes Billy A. , Gloyna Earnest F. 
Published: December 2007

Abstract
The characteristics of wastewaters from petrochemical plants and refineries vary petrochemical plants and refineries vary considerably. Both the quantity and quality may fluctuate significantly within a plant and, between similar facilities, the difference may be even greater.
This paper describes methods of characterizing refinery and petrochemical waste-waters, provides a sequential approach to the development of design data, and describes some design relationships.

Introduction
The refining and petrochemical industries are among the largest water users in the United States. However, water conservation measures combined with process modifications and in-plant control practices have resulted in decreased water requirements within both industries.
The production of petrochemicals, which are defined as those chemicals which originate either totally or in part from petroleum, natural gas, or liquefied petroleum gases, increased five-fold during the period of 1945 to 1960 in 1955 the total production of petrochemicals constituted 24 percent by weight of the total chemical production; and, it is estimated that in 1970 the total production was 41 percent. Estimates indicate that about 500 new petroleum products are introduced to the petroleum products are introduced to the market every year and there is little doubt that the industry will continue to grow and diversify.
It is axiomatic that pollutants discharged from the petroleum industries will increase proportionally and that adequate facilities proportionally and that adequate facilities must be provided to preclude any harmful effects from wastewater effluents.
The successful treatment of wastewaters discharged from refineries and petrochemical plants is predicated on many factors and plants is predicated on many factors and while it is recognized that each industry poses its individual problems, there is a poses its individual problems, there is a logical approach to selecting efficient treatment processes.
Conceptual Steamflood Designs Using Horizontal Wells to Maximise Project Profitability
Authors: Escovedo B. M. 
Published: December 2007

Abstract
Although horizontal wells have amply shown that they improve productivity and accelerate production at a reduced cost per barrel in non-thermal applications, their ultimate impact on thermal recovery is far from fully explored. This work investigates the impact of customising the geometry of horizontal wells for steamflooding to suit a given reservoir architecture. To optimise the well's geometry, consideration first has to be given to the expected shape of the steam zone. Given the shape, wells can be arranged to either maximise the sweep efficiency of steam before steam breakthrough and/or to minimise the negative consequences of steam interference in producing wells afterwards. Three conceptual steamfloods are described which demonstrate the benefits offered by horizontal wells and illustrate how the economics of implementing and operating such floods can improve over historical designs.
The Incineration of Carbonaceous Wastes in Fluidized-Bed Systems
Authors: Smithson G.R. , Wheeler C.M. 
Published: December 2007

Abstract
Fluidized-bed systems have been used in many industries since the first fluidized-bed catalytic cracking unit was installed by the petroleum industry in the late 1930's. Industrial uses include the roasting of sulfide ores, the drying of heat sensitive materials, and many others.
The initial attempt to utilize this technique for the disposal of carbonaceous liquid wastes from the paper industry began about ten years ago with a bench-scale experimental study at the Columbus Laboratories of Battelle Memorial Institute. This research was followed by pilot-scale investigations which led to the installation of the first Container-Copeland commercial unit at the Carthage mill of Container Corporation of America.
Since the first commercial installation, the system which initially was developed has been adapted to the treatment of wastes from several types of pulping operations as well as to the disposal of other carbonaceous industrial wastes. Included in the applications are three which are of direct interest to the petroleum industry:
(1) The disposal of sulfuric acid sludges;
(2) The incineration of oily and caustic refinery wastes; and
(3) The disposal of sludges from the biological treatment of petrochemical wastes.

Introduction
Many industrial uses have been proposed for fluidized-bed systems since this technique was proposed by C. E. Robinson about a century ago. However, it wasn't until the late 1930's that the first commercial fluidized-bed unit involving a gas solids mixture and utilizing elevated temperatures was installed. This installation was the beginning of the use of fluidized-bed catalytic crackers by the petroleum refining industry. Since then fluidized-solids technology has been firmly established as a useful and very valuable industrial tool. The development of this technology for use in many industries has taken years for fruition and new applications continue to be extensively explored.
After its adoption by the petroleum industry, fluidized-bed technology was successfully applied to many operations in other industries where careful control of temperature and gaseous atmosphere and simplicity of operation were needed.
Geomechanics Issues of Steam Assisted Gravity Drainage
Authors: Chalaturnyk Rick , Scott J. Don 
Published: December 2007

Abstract
After successful testing and full scale implementation of the steam assisted gravity drainage (SAGD) process at AOSTRA's (now Department of Energy, Oil Sands and Research Division) Underground Test Facility (UTF), many operating companies are applying this recovery process (or variations thereof) in bitumen and heavy oil projects. The thermal SAGD process with adjacent sets of wellpairs provides a process geometry where the geomechanical response of an unconsolidated sand reservoir may have an impact on the efficiency of the recovery process. This paper describes a series of numerical analyses which illustrate how fluid pressure increases and thermal loading combine to create an optimum stress environment for shear failure of unconsolidated sand formations. Shear failure in dense unconsolidated sands results in a volumetric increase in sand pore volume due to dilation of the sand grains.
To date, bitumen production rates for the SAGD process have been history matched for the UTF Phase A and Phase B tests by increasing the absolute permeability within the formation to a very high value; typically to the maximum value within a range of possible values. It will be shown that for the UTF geometry, absolute permeability increases resulting from dilation in advance of the growing steam chamber is likely a factor in the SAGD process. Due to the nature of SAGD, however, reservoir modelling for UTF scenarios are not be significantly effected since dilation in advance of the steam chamber would create the same "absolute permeability" effect as selecting an initially high absolute permeability value. For different reservoir conditions, such as stress conditions, or wellpair spacings then at the UTF, not including geomechanical phenomena in process simulations may adversely affect the results.
Horizontal Well Application in a High Viscous Oil Reservoir
Authors: Zhou Guanghul , Zhang Rul , Shen Dehuang , Pu Halyang 
Published: December 2007

Abstract
This paper presents the results of scaled model experiments which were conducted to study the possible application of horizontal wells and were used to assess and compare the configurations of horizontal/vertical wells for a type reservoir which is characterized by high viscous oil (11,000 mPa · s at reservoir temperature). The mobility of high viscous oil is limited, so conventional vertical well steamflood is uneconomical. But reservoirs of this type are common in China, thus it is imperative to develop recovery strategies which are likely to succeed in the field, which was the objective of this research.
The scaled model had two vertical wells and four horizontal wells which corresponded to injectors or producers. Experiments of many types of horizontal/vertical well configuration were conducted. Some of which gave favorable results. The horizontal injector-horizontal producer configuration was the best one for the high viscous oil of this study. Horizontal well steamflood can be effective for reducing or preventing steam override and steam channel, the final oil recovery was 54% compared with 35% for a baseline experiment using vertical well steamflood. When steam flow rate increased from 140 cc/min to 170 cc/min, the final oil recovery increased from 57 % to 62%. The preheat phase by steam circulation further improved the final recovery to 78%. The SAGD (Steam Assisted Gravity Drainge) process of horizontal injector-producer configuration not gave good results, it was a very slow process and it's effective drainage area was smaller. The steamflood of vertical/horizontal well configuration was unsuccessful. Temperature measurement and theoretical analysis were used to interpret the results obtained.