bluuebunny/crossref_metadata_2025_split huggingface dataset:
Application and Method Based On Artificial Intelligence for Selection of Structures and Screening of Technologies for Enhanced Oil Recovery
Authors: Ibatullin R. R. , Ibragimov N. G. , Khisamov R. S. , Podymov E. D. , Shutov A. A. 
Published: December 2007

Abstract
Main fields of the Republic of Tatarstan in Russia entered late stage of development. In recent years more than 60 methods on enhanced oil recovery and stimulation of producing wells have undergone comprehensive tests in a wide range of geologic conditions. Based on geologic information and experience of fields development there have been created geologic and hydrodynamic models for analysis and forecasting of technological indices of oil production, as well as data bases on application of methods for enhanced oil recovery and stimulation of wells.
Based on artificial intelligence, procedure is developed for selection of enhanced oil recovery method using model of residual reserves for different structures of development. Models apply neural network, capable to synthesize recommendations based on training by data base for realization of more than 60 methods on enhanced oil recovery and wells stimulation at similar structures of Tatarstan fields. These technologies are characterized by a set of criteria, including data on reservoir, formation fluids, operating conditions of wells, information on peculiarities of the technologies application. Models are trained on more than 2200 examples, reflecting correct conditions of realization of EOR and stimulation technologies, using considered technologies. During testing more than 70% of data sets are confidently recognized, which correspond to criteria of application of enhanced oil recovery methods, realized through injection wells, and more than 90% of methods on wells stimulation.
The developed procedure allows to forecast and rank the application of different methods for enhanced oil recovery and stimulation of wells at specific producing and injection wells in real-time operation mode. This procedure is used in conditions of fields development in the Republic of Tatarstan.
The conducted work allows to combine two modern approaches - modeling of field development and application of artificial intelligence for selection of most effective technologies on enhanced oil recovery and stimulation of wells. Data base has been developed for methods of enhanced oil recovery and stimulation of wells for conditions of Tatarstan fields.
Foam Generation in Porous Media
Authors: Gauglitz P. A. , Friedmann F. , Kam S. I. , Rossen W. R. 
Published: December 2007

Abstract
In steady gas-liquid flow in homogeneous porous media with surfactant present, there is often observed a critical injection velocity or pressure gradient ∇pmin at which "weak" or "coarse" foam is abruptly converted into "strong foam," with a reduction of one to two orders of magnitude in total mobility: i.e., "foam generation." Earlier research on foam generation is extended here with extensive data for a variety of porous media, permeabilities, gases (N2 and CO2), surfactants, and temperatures. For bead- and sandpacks, ∇pmin scales like (1/k), where k is permeability, over 2 ½ orders of magnitude in k; for consolidated media, the relation is more complex. For dense-CO2 foam, ∇pmin exists but can be less than 1 psi/ft. If pressure drop, rather than flow rates, is fixed, one observes an unstable regime between stable "strong" and "coarse" foam regimes; in the unstable regime ∇p is nonuniform in space or variable in time. Results are interpreted in terms of the theory of foam mobilization at a critical pressure gradient.
Further Development of the Pore Scale Mechanism of Relative Permeability Modification by Partially Hydrolysed Polyacrylamide
Authors: Singleton M. A. , Sorbie K. S. , Shields R. A. 
Published: December 2007

Abstract
One proposed method for the chemical control of produced water is by using a "relative permeability modifier" (RPM) which is usually based on a water soluble polymer. A considerable amount of literature on such materials has appeared although there is still not a complete consensus on the actual mechanism through which RPMs operate within a porous medium. One mechanism that has been suggested is based on the existence of an adsorbed polymer layer where this layer, within a water-wet porous medium, reduces water flow more significantly than oil. In this paper, we propose further developments of this adsorption mechanism of relative permeability modification. The present study is based on two complementary approaches as follows: (i) a series of detailed coreflood experiments has been performed to assess the impact that an adsorbed polymer layer has on the fluid flow pathways. Experimental results on tracer pulses, end point relative permeabilities/saturations and pressure profiles have been utilised in our analysis; (ii) a pore-scale network model has been developed which incorporates the proposed mechanism of RPM operation. The predictions from this model have then been compared with the experimental results. It has been possible to deduce that, not only is water flow affected more significantly than oil, but that the manner in which this occurs is different for each phase. The contributions to both the water and oil conductivity of relative permeability effects (due to saturation changes) and actual "pore blocking" is deduced.
Pore Microstructure and Fluid Distribution in a Diatomaceous Reservoir
Authors: Ross C. M. , Kovscek A. R. 
Published: December 2007

Abstract
This study was undertaken to improve our understanding of fluid distribution and flow behavior by quantifying pore type, pore body size, shape attributes, and throat sizes of pore networks in diatomaceous reservoir rock. This work is a first step toward providing a means of integrating different measurement types and establishing an interpretive tool for understanding laboratory results and field behavior. This project lays the groundwork for developing a predictive tool that can be utilized to generate input for reservoir simulator studies.
The pore microstructure of 11 diatomite samples from Lost Hills Field (Kern Co., CA) and one quarry sample was quantified using image analysis of photomicrographs collected with a Scanning Electron Microscope (SEM) in backscattered electron (BSE) mode. Six distinct pore types were identified ranging from small, irregularly shaped pores to large moldic and intraskeletal pores as well as large interconnected, intergranular pores. The throat size average and size range for each pore type was established by combining image analysis information with high-pressure mercury injection measurements. Once this relationship is determined, the pore body size and throat size serve as the basis for a predictive model allowing capillary pressure curves and fluid saturations to be calculated from pore type data.
In this study, the relationship between pore types, fluid flow, and fluid distribution indicate a dual porosity system. Permeability is primarily controlled by three pore types, which represent 1 to 28% of the total core porosity and 0.67 to 9.75% of the total volume. Fluid saturation models were developed to provide an accurate means of calculating oil and water saturations as well as their distribution within the pore network for both the reservoir and core samples. From the model, we found that the most permeable pore types have oil saturations that are 5 to 35% lower than reservoir saturations. This indicates that the oil is moveable and can be swept from permeable pore types. Alternatively, there was no net change in saturations for the remaining pore types between core- and log-derived saturations. For these pore types, spontaneous imbibition is the most likely production mechanism. The smallest pore type is predominately water filled with oil saturation values of about 32% in both the reservoir and core samples.
The proportion of each pore type can be predicted from wireline log data and used as input for the predictive capillary pressure model and fluid saturation models. This allows the models to be applied to the rest of the field providing data for field development decisions and simulator input.
Darcian Dynamics: A New Approach for the Mobilization of Ganglia in Porous Media
Authors: Amili Pouya , Yortsos Yanis C. 
Published: December 2007

Abstract
A number of problems in porous media involve the simultaneous flow of two immiscible fluids. As a result of the capillarity of the porous medium, however, the flow occurs in an intermittent way, in which phases may get trapped, immobilized, or conversely mobilized due to the flow of the other phase. This process of ganglia motion has been described in detailed past works by various authors using elaborate pore-network simulations. In this paper, we apply a different approach, in which all the hydrodynamic information of the flowing fluid and the effect of the various ganglia enters at the various ganglia interfaces using a boundary integral method. Methods of this type have been extensively used in potential theory, but have not been applied in the context of flow and mobilization of immiscible fluids in porous media. Their advantage is that the hydrodynamic problem is mapped at the ganglia interfaces and allows a fast and convenient way to describe the forces on the disconnected phase, the possible mobilization, stranding, coalescence, crowding effects, etc.
We present the method development by deriving the integral equation to be solved on the fluid interfaces. We then use a numerical method for its solution and examine a variety of problems including: the condition for the mobilization of a stranded ganglion as a function of the capillary number and the ganglion shape; its subsequent motion in the random capillary environment and the rate of stranding or coalescence; effects of gravity; and the interaction between neighboring ganglia. The latter does not always enter as a crowding effect, as intuitively expected. The method finds applications to problems where the flowing phase is disconnected, as for example in foamy oil flow or the countercurrent flow of steam-water in the presence of gravity.
Effect of Trapped Foam on Gas Tracer Diffusion in a Visual Microflow Model
Authors: Nguyen Quoc P. , Thissen Michiel H. G. , Zitha Pacelli L. J. 
Published: December 2007

Abstract
Foam (i.e., dispersion of gas in surfactant solution confined in porous media) is an excellent acid diversion and gas-blocking agent. In these and other applications, fluid flow control depends strongly on the ability of foam to enhance gas trapping. This was recognised long ago but the relation between gas trapping and flow reduction by foams is not well understood. Several authors proposed to use a tracer dispersion technique to quantify the amount of gas trapped in porous media during foam displacement. However, this technique may suffer limitations due to diffusion of tracer into the trapped foam. The purpose of this paper is twofold. (a) To check the validity of this technique, we study the resistance of one or more foam films to gas tracer mass transfer using our original method of ‘freely-standing’ film in a straight tube. (b) We estimate trapped gas saturation for several foam textures using visual micro-flow model experiments. Gas is injected into the model and its concentration is monitored at the outlet. The difference in tracer history between a dry model and a micromodel with foam placed inside is characteristic for the trapped gas fraction.
Multiple-Scale Stabilized Finite Elements for the Simulation of Tracer Injections and Waterflood
Authors: Ruben Juanes , Patzek Tadeusz W. 
Published: December 2007

Abstract
We present a numerical method for the simulation of misci- ble and immiscible multiphase flow in porous media, with emphasis on the advection-dominated case. A fractional flow formulation is adopted, resulting in a "pressure" equa- tion and a "saturation" equation. The key idea of the pro- posed methodology is a multiple scale decomposition of the variable of interest into resolved and unresolved scales. This acknowledges the presence of fine scales which can- not be captured by any grid, but whose influence on the coarse scales is not negligible. The multiscale approach leads to a stabilized finite element formulation, which pre- vents global spurious oscillations of the numerical solution without introducing excessive dissipation. The method is further improved by incorporating a novel shock-capturing technique based on a nonlinear dissipation mechanism pro- portional to the absolute value of the subscales. We be- lieve this approach is entirely new in the context of flow in porous media. Numerical simulations of tracer injection (miscible flow) and waterflood (immiscible flow) are presented. The proposed subgrid scale method with shock- capturing shows exceptional performance in all test cases studied. These test cases illustrate the potential and applicability of the proposed formulation for solving multiphase compositional flows in porous media.
Metering For Custody Transfer And Royalty Computations
Authors: Clausen R.E. 
Published: December 2007

1961 Middle East Reg. Mtg. Dhahran, Mar. 27–29, 1961
The oil industry has been interested for many years in the use of meters for custody transfer and royalty computations rather than by the generally accepted practice of hand gaging of tanks. The reasons for the interest are; the savings of expenditures for installation of tankage, which in turn reduces evaporation losses; provides for more flexible and efficient operations, resulting from increased use of facilities such as tankage, pipelines and ship loading facilities by reducing waiting time necessary for manually taking opening and closing gages; labor savings in those cases where metering can be made automation and unattended. Another reason is the possibility that metering is more accurate than manual tank gaging, which benefits both parties where royalties are involved.
Prior to 1942, research on the accuracy of positive displacement meters was done by the American Society of Mechanical Engineers. Since then, guidance of research has been a joint venture by ASME and American Petroleum Institute committees. Standard methods were developed for design, research, testing and operation of meter measurement of liquid petroleum hydrocarbons by positive displacement meters. These methods were included in ASIDE publications, National Bureau of Standards Handbooks, the API Standard 1101 and other publications. Because of the need, about the year 1956, high capacity turbine type meters were developed and larger positive displacement meters were built. It is understood that because of the increasing use of turbine meters which are becoming more accurate, the API is changing the name of their "liquid positive displacement committee" to "liquid measurement committee."
Advance Drill Bit Designed For Minimum Cost Drilling
Authors: Sheshtawy A.A. 
Published: December 2007

Abstract
The Tri-Max* is a new bit developed after five years of research and field tests with the main objective of minimizing the drilling cost. The trade name Tri-Max stands for:–Maximum Footage–Maximum Rate of Penetration–Maximum Safety
The Tri-Max bit runs have achieved a 38% increase in the penetration rate compared to tricone bits of the same class.
The Tri-Max drill bit is completely different in configuration and performance from the tricone bit developed by H. R. Hughes in 1933, and still widely in use for oil well drilling. The Tri-Max bit's solid steel body's general configuration, when viewed from the side, is that of an inverted triangle with an upper full gage stabilizer section, intermediate taper section and a lower nose section. The patented cutting structure arrangement on patented cutting structure arrangement on the Tri-Max bit body will achieve self-advancing of the bit under reduced bit load compared to the conventional tricone bit, and hence ensure straight hole drilling. The transfer stress relief openings on the Tri-Max bit body encourage the rock failure by tension and shear, a process far more efficient than compression and shear, the rock failure mechanism inherent to conventional tricone and diamond drag bits.

Introduction
Drilling a deep oil or gas well is a fascinating and challenging job, but the optimization of the drilling operation in these deep wells is difficult to achieve due to the inherited weakness of the tricone bit, especially 8 1/2" in diameter or smaller. As the well gets deeper, and the formation becomes harder, the size of the hole becomes smaller, and with that, a tangible reduction of the tricone bit parts. At these depths, the friction between the drilling string and the hole increases, and the weight on bit and the tricone bit's cutting elements rotation at the bottom of the hole has a weak relation, if any, to what we observe and record at the surface. Consequently, most of the tricone bits run in deep exploration wells are more or less a trial and error experiment. In the last few years, the weakness of the tricone drill bit, especially for drilling deep wells, has been recognized by numerous individuals and organizations seriously involved in the drilling industry. The Tri-Max drill bit is a product of this effort.
Implementing Steam Assisted Gravity Drainage Through Combination of Vertical and Horizontal Wells in a Super-heavy Crude Reservoir with Top-Water
Authors: Gao Yongrong , Liu Shangqi , Zhang Yitang 
Published: December 2007

Abstract
Guantao formation in Du84 block, Liaohe oilfield is a typical massive block extra-heavy oil pool with top-water. The oil viscosity is very high and the formation thickness is great. Bitumen shell with 3~4m thickness exist between the top-water layer and oil column. If the bitumen is dissolved when heating in the steam injection recovery process, the top-water will flow down. Moreover, the field production showed that conventional steam stimulation recovery with vertical well is poor. New methods and technologies have to be researched and tested to improve the oil recovery, decrease operation cost and enhances economic efficiency.
Numerical simulation results showed that the reservoir can be developed efficiently by implementing Steam Assisted Gravity Drainage (SAGD) process using existing vertical well and horizontal wells to be drilled following steam stimulation. To avoiding top water going down, the new well completion methods have to apply, and the upper portion of the formation in the steam injector shouldn't be perforated. If the viscosity of the bitumen shell is greater than 500×104mPa.s, the 20m thickness of upper portion shouldn't be perforated to inhibit the top-water effectively. If the viscosity of the bitumen shell is 50~200×l04mPa.s, the thickness of upper portion not perforated should be more than 30m to inhibit the top-water effectively. At the same time, the results also showed that the heat communication between the wells is an important factor to control the top-water. The SAGD process can be implemented only when heat communication is established by steam stimulation in order to inhibit the top-water.
Feasible Evaluation of Natural Gas Floods in Wennan Low Permeability Reservoirs
Authors: Li M. , Hu Y. Q. , Zhao J. Z. , Huang Z. G. , Wu Y. 
Published: December 2007

Abstract
This presentation provides a technical overview of a project that evaluated the feasibility of natural gas injection in a Wennan low-permeability sandstone reservoir. An advantage of gas injection is high injectivity. Relative high injectivity combining with near miscible condition between injection gas and reservoir fluid offers a potentially attractive prospect in the Wennan low-permeability reservoir. Zhongyuan Oil Field and Southwest Petroleum Institute(SWPI) sponsored the project at Wennan field, including reservoir characterization, experiments, flow simulation, and nitrogen injection, which proved that a high gas injectivity and reservoir pressure was 44.35 MPa.
Main attention in this paper is paid to experimental research, including the regular PVT test. The slim-tube tests were used to determine minimum enriched gas composition(MMC) for miscible displacement at present reservoir pressure. The experiment was conducted at pressure 44.35 MPa and 393K. These slim-tube tests showed that a lean gas with reservoir fluids can reach near-miscible condition. Only a few LPG are needed to enrich the the lean gas.Then a set of experiments to quantify displacement efficiency and provide parameters for composition simulations.The first experiment evaluated the recovery efficiency in sandstone by enriched gas displacements, and the second looked at the recovery in sandstone by lean gas. These experiments showed the enriched gas breakthrough as 0.92HCPV in the typical miscible condition, final recovery to be 87.01%, and lean gas breakthrough(0.437HCPV) with recovery at 65.29%, as in immiscible displacement. However, substantial recovery after breaking(0.5HCPV with final recovery 85.29%) suggests an efficient extraction of intermediate components in the typical volatile oil. Additionally, the experiments in the project was
conducted to evaluate water flooding and WAG flooding. WAG flooding showed that WAG could significantly increase oil recovery, but the pressure difference would increase greatly when gas was injected. Therefore, WAG is not suggested in Wennan oilfield.
Further investigation was made at field with CMG 3D compositional simulation. Compositional simulation suggested slow breakthrough and high recovery at the Wennan field. These evaluations will lead to a pilot test in the Wennan low-permeability reservoir.
A Field Proven Analytical Method to Resolve the Open Hole Volume Gravel Packed in a High Angle or Horizontal Well, Enables Enhanced Pre-job Simulation.
Authors: Nelson Roy N. , Onwa Sam 
Published: December 2007

Abstract
This paper demonstrates an analytic approach to measuring the success of horizontal, open hole gravel pack completions. The approach is discussed using five UK North Sea case histories in which a post job evaluation was used to determine the percent of the open hole successfully gravel packed in each well. The method was verified in the field using radioactive tracer and / or temperature logs in three of the five wells with 3000 ft to 5000 ft horizontal open hole sections. The method closely estimates, without intervention, the actual Effective Open Hole Diameter, Deff, following drilling and hole clean-up operations. Using Deff, the observed Alpha Ratio, and an iterative match point technique, the actual lengths of the open hole gravel packed were computed. The method also corrected existing simulation procedures for calculating the volume of sand placed in the cased section above the sand control screens.
During the pre-job planning or simulation phase, an incorrect estimate of open hole diameter can result in erroneous estimates of transport velocity, dune height ratio, minimum pump rates required to avoid sand duning in the work string, the Alpha and Total Pack Time, and the sand and slurry volumes required. In addition, the relative success of the gravel pack could not be correctly measured, using previous methods where only the theoretical open hole diameter and measured sand slurry volume were known.
This proven Alpha Ratio analytical method provides an insight to the actual Effective Open Hole Diameter, enabling continuous improvement through enhanced pre-job simulation of subsequent project wells.