bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Study to Determine the Moveable Fluid Porosity Using NMR Technology in the Rock Matrix of Xiaoguai Qilfield
Authors: Wang Weimin , Miao Shen , Liu Wei , Sun Dianqin , Chaohui Ye 
Published: December 2007

Abstract
Xiaoguai oilfield, which is located in the north-west of China, is an oil field with typical low porosity and low permeability. It is very important to determine the recoverable reserves during the development of the oil field. The high paramagnetic mineral content and severe lithology inhomgeneity, caused by diluvial deposit, make the NMR measurement complex and difficult. This paper illustrates a low field NMR technology to determine the recoverable fluid in the rock matrix of Xiaoguai field. The NMR results are also compared with other petrophysics methods, such as mercury injection measurement and scanning electron imaging analysis. Due to the high paramagnetic material content and the serious filling of the intergranular pores by chlorite clay, the T2 cutoff of the moveable fluid is much shorter (about 5ms) and the moveable fluid amount is very low.
P. 255
Mechanism Study and Application of Preventing Water Channeling by Cementing
Authors: Yan Shicai , Luo Changji , Yang Zhiguang , Liu Ailing , Cheng Yan 
Published: December 2007

Abstract
This paper focuses on the mechanism of pressure decrease and gel strength of coagulated process for cementing slurry. From the study, their law and feature and their internal relation have been found. On this basis, critical condition of anti-channeling has been established. The concept of "stable press coefficient" have been proposed and used to quantitatively express the degree of stable press after cementing for the high pressure acquifer, so that it provides the basis for analysis of cementing quality and design of cementing implementation.
On the basis of mechanism study, lock-water anti-channeling agent has been developed successfully. It has been used in oil well cement of A grade, which makes the cement slurry characteristic of rapidly developing gel strength short critical time, micro-expanding volume and high bonding strength of interface etc.. So it has an obvious effect on anti-water channeling after cementing.
P. 287
Stress Sensitivity of Naturally Fractured-porous Reservoir with Dual-porosity
Authors: Duan Yuting , Meng Yingfeng , Luo Pingya , Su Wanyong 
Published: December 2007

Abstract
Compared with porous sandstone reservoirs, the complicated fractured (fractured-porous) reservoir is of high stress sensibility. This results in not only the difficulties of calculating transport properties of actual formations, but also problems on formation protection. The stress sensibility of the reservoir results mainly from that of fractures in the reservoir. Therefore, the topologic properties of both natural and many man-made fractures without any grinding, taking from both actual reservoirs and crops on the ground, are investigated and analyzed with elastic and elastic/plastic micro-contacting theory. Then the stress sensibility of fractures is numerically modeled on computer and tested in lab. Some conclusions different from that of publications are obtained. Consequently, a method of analyzing and evaluating stress sensibility of dual-porosity reservoir with natural fractures is made on the basis of the investigation. This can thus be applied to the calculation of in-situ transport property for naturally fractured reservior and provide basic data for the formation protection of porous fractured reservoirs.
P. 295
Systematic Fracturing Technology and its Application in the Development of Low-Permeability Reservoir
Authors: Jiang T. , Shan W.W. , Ding Y.H. , Wang Y.H. , Wang Y.L. 
Published: December 2007

Abstract
It is an advance in hydraulic fracturing technology from single well fracturing to reservoir systematic fracturing. Taking a low-permeability reservoir as a unit, the systematic hydraulic fracturing technology is to obtain the maximum net present value by balancing producing rates, recovery efficiency and economic benefits under certain combination of hydraulic. fracture and flooding pattern. The research of systematic hydraulic fracturing involves the study of reservoir engineering and fracture mechanics of hydraulic fracturing and the optimum design of frac fluid system. The establishment of the system of systematic hydraulic fracturing technology is based on comprehensive interaction of multiple discipline.
This technology has already been executed in the marginal reservoirs of low permeability, such as Tuha Shanshan, etc., achieved important economic efficiency, and provided new way & methods for the development of low-permeability reservoirs.
P. 303
A Feasibility Research Method and Project Design on CO2 Miscible Flooding for a Small Complex Fault Block Field
Authors: Lu Lianhai , Liu Bingguan 
Published: December 2007

Abstract
The paper introduces the feasibility research method on how to study CO2 miscible flooding, including mechanics experiments, physical simulation experiment, numerical simulation and economic evaluation. Development plan is optimized on a pilot project based on a comprehensive evaluation of wells' conditions, equipment ability and CO2 supply ability in a small complex-fault-block, water-out, sandstone reservoir.
P. 501
Application of Sidetrack Horizontal Well in Conglomerate Reservoirs at Mid-High Water cut Stage to Improve Development Effects
Authors: Qin Jianhua , Yang Ruiqi , Chi Jianping , Cheng Shouyun , Dai Canxing , Liu Liangcai 
Published: December 2007

Abstract
Based on the study of remaining oil distribution and detailed reservoir description, the design optimization and field test of sidetracking horizontal drilling (SHD) in Xinjiang conglomerate reservoirs has been done. Single well production rate of two SHD wells is 2-3 times that of the average rate in the test area. That shows the technique can improve development effect of the conglomerate reservoir at mid-high water cut stage. Accurate geological description and reservoir engineering study are the key factors to the success of SHD, and to select a proper completion method is also important for the development of old field with complicated multi-bed sets. The application of SHD is limited in small ranges with small formation penetrating thickness. Therefore, we present a modified concept for the development of the aging field, SHD takes the leading role while conventional horizontal drilling and vertical drilling are the supplements.
P. 545
An Efficient Method for Enhanced Oil Production Providing an Increase in Oil Recovery Index
Authors: Shaposhnikov V.M. , Listengarten L.B. , Tseytlin S.D. , Mendelevich L.M. 
Published: December 2007

V.M. Shaposhnikov, SPE, and L.B. Listengarten, and S.D. Tseytlin, SPE, and L.M. Mendelevich

Abstract
PEn Technology was developed for high-GOR oil fields. The target was the optimization of well-formation system by means of maintenance of bottomhole pressure and supporting fluid lift. The technology applies an individual approach to each well, based on analysis of numerous parameters and data, computer simulation of well-formation system and sizing calculation for the technology's bottomhole tools.
P. 371
Design of Casing Strings
Authors: Bowers C.N. 
Published: December 2007

Abstract
Considerable economy can be effected by designing each casing string individually for the particular set of conditions involved. The paper discusses methods and procedures for incorporating all of the important variables in the design of individual strings, and step-by-step examples are given. If the casing is never empty, the problem is quite simple and can be solved very easily. While oil strings may or may not at sometime be empty, surface and intermediate strings are seldom, if ever, empty and, therefore, are not subject to collapse loads. Design charts and the usual design methods provide for collapse and tension loads occurring simultaneously. It is extremely improbable that these loads exist at the same time. A practical method of designing casing strings to provide both tensile strength and collapse resistance at the time each is needed is presented. Strings designed by this method will be much cheaper than those selected from charts or designed by the usual computation methods. This economy is realized along with adequate safety.

Introduction
The design of casing strings has long been a problem to the engineer. Many elaborate charts have been prepared to ease the task of. the designer. These charts are a form of standardization and while standardization is usually a goal much sought after, it has doubtful value in the design of casing strings. There are so many factors involved that it is impossible to include them in any set of charts. Consequently the use of available charts has resulted in thousands upon thousands of tons of steel being buried in the ground needlessly which, of course, represents dollars wasted. This can be corrected by designing strings on an individual basis. The purpose of this paper is to outline all of the required computation methods and procedures and show how the many variable factors can be incorporated into the design of individual strings. A safe, economical method for designing strings is also presented which provides for various load conditions when they occur.

Factors To Be Considered
In the past most casing strings, whether selected from charts or designed by computation methods, have been based on the assumption that the casing is empty (and, therefore subjected to a full head of mud) and at the same time is hanging in air. Obviously this is an inconsistency. The effect of tension on collapse resistance is considered, but the effect of buoyancy is neglected and yet if collapse acts on an empty string, a buoyant force in excess of the total weight of mud displaced by the casing wall must exist. Buoyancy puts at least some of the casing at the bottom of the string in compression. Compression stresses increase the collapse resistance just as tension stresses decrease it.
New, Low Viscosity Acid in Oil Emulsions
Authors: Crowe C.W. , Miller B.D. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the 49th Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Houston, Texas, Oct. 6–9, 1974. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made. provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
A highly retarded acid emulsion has proven extremely effective in the stimulation of hot limestone and dolomite formations. The level of reaction rate retardation achieved with this acid is much greater than previously possible and is obtained through use of a unique surfactant system which both emulsifies the acid and forms a chemical barrier on the surface of the rock. Acid reaction rate studies performed in the laboratory under both static and flowing conditions demonstrate its high level of retardation.
In contrast to previous emulsified acids, which depend upon high viscosity for retardation, this emulsion has a viscosity of only 30 cps, thus greatly reducing pumping pressure and allowing increased injection rate. Due to its slow reaction rate and improved pumpability, acid penetration distance is greatly increased. penetration distance is greatly increased. Comparative well results clearly demonstrate the increased effectiveness of this type retarded acid.

Introduction
Most acid treatments can generally be classified as either fracture or matrix acidizing. Matrix treatments are performed at pressures below that required to produce pressures below that required to produce hydraulic fracturing and have as their main purpose the removal of formation damage in the purpose the removal of formation damage in the area immediately around the wellbore. Acid fracturing treatments are performed at pressures above fracturing pressures, usually at greatly increased injection rates. These treatments are designed primarily to improve the natural flow characteristics of the well by the creation of artificial flow channels deep into the formation. In contrast to ordinary hydraulic fracturing where fracture conductivity is produced by the placement of sand or other propping agents acid fracturing achieves conductivity by the nonuniform etching of the fracture faces.
Chemical Composition of Deep Subsurface Waters of the Western Anadarko Basin
Authors: Dickey Parke A. , Soto Carlos 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Five different chemical types of water are found in the Oklahoma panhandle area, each type characteristic of a particular geological zone. The Permian of the Hugoton-Panhandle field contains concentrated chloride-calcium brine, which resembles normal connate water except that it is unusually rich in sulfate (Type V). The Pennsylvanian sands above the Morrow (Lansing, Pennsylvanian sands above the Morrow (Lansing, Tonkawa, and Toronto) contain normal chloride-calcium connate water (Type Y). The Oswego sands contain similar water, somewhat less concentrated (Type W). The Morrow sands contain three different types: in Cimarron County, Okla., a high-sulfate, chloride-calcium brine resembling Type V (Type X); in Texas County, the normal chloride-calcium brine (Type Y); and in Beaver County eastward to Blaine County, a very strange, dilute water containing appreciable amounts of carbonate and sulfate (Type Z).
The origin of the different chemical types is quite puzzling. The dilute waters of Type Z are especially anomalous, for they resemble meteoric waters chemically, although there is no hydrodynamic circulation at the present time. They may be ancient meteoric waters trapped by the uplift of the Amarillo-Wichita mountains shortly after deposition of the Morrow sediment or they may be "immature" connote waters similar to those reported from the abnormally pressured areas of the Gulf Coast Tertiary.

Introduction
Deep subsurface waters associated with the oil and gas of the Texas and Oklahoma panhandles vary widely in their chemical composition. Those of the Morrow are especially interesting because they range from strong chloride-calcium brine with the total solids content of 100,000 to 200,000 mg/liter, to relatively fresh bicarbonate-sodium waters with a total solids content of 10,000 to 30,000 mg,/liter.
Connote waters have been defined as waters that have been removed from the hydrologic cycle by burial in sediments for substantial periods of geologic time. They must be remains of ancient sea water, but their composition is drastically altered. Normally they lack bicarbonate and sulfate, and are much more concentrated than sea water. The concentration often increases with depth and age.
Meteoric waters may be defined as waters that have been part of the hydrologic cycle recently, geologically speaking. They are usually circulating, entering the aquifer (waterbearing permeable formation) at an outcrop of high elevation and leaving it at a low elevation. Chemically, they are comparatively fresh and vary widely in composition.
Coiled Tubing Hangoffs: A Simple, Yet Effective Tool for the Future
Authors: Allbee James D. 
Published: December 2007

Abstract
During the life of most gas wells, lifting technology is needed to help produce gas. There are a lot of reasons for this. As reservoirs deplete and pressures drop, the energy of the reservoirs may not be sufficient to unload gas and liquids in a consistent fashion. In addition to natural production declines, the produced oil and water may serve to choke the well as the well loads up and hydrostatic pressure at the producing zone increases. Operators may try various things to keep their wells producing when this is the case. For instance, compressors are installed to lower minimum line pressures, and downhole pumps and gas-lift are installed to remove liquids. Temporary measures may include workovers to swab liquids or blow liquids out of the well with nitrogen, dropping soap sticks and venting the wells to the atmosphere. One of the simplest permanent measures to control this loading phenomenon in wells is the installation of velocity strings.
Twenty-one velocity strings were installed for one operator between June 1996 and August 1997. These wells are in various regions of Oklahoma, producing from different formations and depths. In an attempt to classify the success and viability of these installations, ten of these wells were studied. The project concentrated on obtaining a good reservoir and well model which, first, predicted the necessity of these services and, second, modeled post-job production. A thorough documentation of the methodology for this study is included along with the results. The average project well had 4100 cumulative days on production before the coiled tubing hangoffs were installed. 8 of the 10 wells had positive net present values, with the cumulative net present value of the 10 wells analyzed to be $238,000 in 250 days. Pay-outs for the wells averaged 130 days. The study shows the importance of looking at each candidate well individually, and confirms the economic viability of hanging coiled tubing as a permanent, hassle-free completion.
Formation Sand Liquefaction: A New Mechanism for Explaining Fines Migration and Well Sanding
Authors: Hayatdavoudi A. 
Published: December 2007

Abstract
An exhausting review of oil field literature showed us a wide range of causes for fines migration. Conspicuous among these causes was the existence of kaolinite clay mineral in the pores and the intensity of mass and momentum transfer of the fluid within the wetted perimeter of pores or pore throats. However, the field production operation personnel have taught us that when the water cut rises, the fines migration and well sanding becomes a serious, costly issue for the operators. It appears that neither researcher in the laboratory nor field researchers have offered clear reasons for the fines migration when the water-cut increases above and beyond a certain threshold. This paper addresses this issue with some examples. These examples may be used as bases of recommendations for resolving the fine migration issue. To understand the issue first, (for the purpose of offering some remedial measures), our works led us to examine a new mechanism, sand liquefaction. In this effort, we discovered that as the original water-oil contact plane rose above the original plane of contact resulting from water conning or very high rate production, the formation sands began to liquefy. It appeared that five important parameters controlled the sand liquefaction process. They were the fine particle buoyancy, changes in the effective bulk density of sand, high pore pressure build-up near the well bore due to transient pressure (equivalent to transient shear stress), lack of adequate cohesive cement between sand grains, and a low angle of internal friction. Our calculations lead us to conclusion that if the fine particles accelerate above the threshold limit of 0.190 g, where "g" is the acceleration of gravity, the sand liquefaction begins. The obvious outcome of this process is well sanding, fines migration, or both. Although not discussed in this paper, we detected that if the amount of natural cementing material, such as calcite, dolomite, and siderite, reached a level of about 5 percent or more, the sand would not liquefy easily. Our recommendation for remedial works like gravel packing, frac packing, selectively perforating the sand, trajectory planning for well re-entries, and other measures is largely based on these conclusions and microscopic determination of the sand shear strength.
Well Optimization Package for Progressive Cavity Pumping Systems
Authors: Klein S. T. , Thrasher W. B. , Mena L. , Quijada E. , Brunings C. 
Published: December 2007

Abstract
The subject Progressive Cavity Pump Optimization System (PCPOS) continuously analyzes analog system values from several components at the surface to determine the operating fluid level of a well. One major component is a load-measuring device integral to the surface drive system. No down-hole sensors and/or wires are required. Analyses of the input values by the PCPOS software provide optimum pump operation criteria related to the dynamics of the producing well.
Finite Element and Neural Network Modeling of Extreme Overbalance Perforating
Authors: Azari Mehdi , Asadi Mahmoud , Schultz Roger , Ghalambor Ali 
Published: December 2007

Abstract
Finite element modeling (FEM) was used to study the micro-fracture propagation around perforation tunnels created after an extreme overbalanced perforating (EOBP). The effectiveness of the EOBP as a function of formation permeability and the overbalanced pressure was investigated.
The results of the FEM were used to train and generate an artificial neural network (ANN) for EOBP conditions. This neural network model may then be used to quickly investigate the effects of using different overbalanced pressures and various formation permeabilities on flow rate.
Effect of Drill Pipe/Coiled Tubing Initial Configuration on Contact Force
Authors: Qiu Weiyong 
Published: December 2007

Abstract
The contact force between the drill pipe and the wall of a bore hole has been studied intensively in the past1–6. Formulas have been provided to predict the contact force for the drill pipe which is initially straight and finally changes into either a sinusoidal configuration or a helical configuration. Recent publications7, 8 indicate that the residual bending of the drill pipe has significant effect on the post buckling behaviors of the drill pipe in deviated and curved well bores. No papers has been published regarding the effect of the residual bending of the drill pipe and CT on contact force.
This paper presents a novel approach to investigate the effect of the initial drill pipe/coiled tubing (CT) configuration on the contact force between the drill pipe and the wall of a bore hole. The initial drill pipe configuration is assumed to be a sinusoidal configuration. In order to simplify the problem, only the helical configuration is assumed to be the final drill pipe configuration. By using the Lagrange Multiplier method, the change in the total potential of the conservative system is formulated. Setting the first order variation of the change in the total potential to zero yields the force equilibrium equations. The contact force for a drill pipe constrained within a well bore (vertical, inclined, and curved) can be achieved by solving the equilibrium equations simultaneously. Numerical examples are presented for the drill pipe and CT in vertical, deviated, and curved wells, respectively. The results show that the residual bending of the drill pipe increases the contact force.