bluuebunny/crossref_metadata_2025_split huggingface dataset:
Efficient Use of Streamline Simulation and Inversion Techniques to Improve Reservoir Modeling
Authors: Sarkar Amit K. , Faruqi Sohail A. , Barman I. , Wang M. K. 
Published: December 2007

Abstract
Benefits of a 4-step reservoir modeling process to properly manage highly uncertain permeability models are demonstrated. Streamline simulation generates results that compare reasonably well with conventional simulation results, but provides much greater speed.
Multiple permeability distributions were screened at the fine grid level using a streamline simulator, and improved further using an inversion simulator. The streamline simulator was also used during the upscaling process to screen the upscaled models. The resulting permeability model with lower uncertainty is more appropriate as input to conventional simulators for production data history matching, and forecasting.
Drilling Program Financing and the Operator Risk/Return Position
Authors: Batt Robert 
Published: December 2007

Society of Petroleum Engineers 6200 North Central Expressway Dallas, Texas 75206
THIS PAPER IS SUBJECT TO CORRECTION
American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Introduction
The purpose of the drilling program is to raise venture capital for exploration and, to a lesser extent, development activities of petroleum producers. As a financing form, petroleum producers. As a financing form, although not entirely unique, it is particularly well adapted to the petroleum industry. The programs are able to capitalize on -the various features of the industry to provide an investment package that is attractive to (wealthy) outside investors.
Drilling programs are joint ventures, usually organized as limited partnerships, which permit petroleum operators and outside investors to participate in petroleum exploration and development. The operator assumes the role of general partner with the outside investors becoming limited partners. One feature of these programs is that they permit the pass-through to the outside investor of any tax benefits of the venture. Although this is the feature that receives the most attention, it is not the main purpose of these programs.
To the operator, the drilling program form of financing provides an additional degree of flexibility that is not available through more traditional financing sources. By taking advantage of this flexibility, the petroleum operator can not only obtain the needed financing, but can also receive other benefits.
Goals such as meeting current cash needs and providing continued support of the technical operations of the petroleum operator are also met by drilling programs. However, the target of this paper is to concentrate on the effects on the operator's risk/return position. It is aimed at showing how specific features of drilling programs provide the means of achieving satisfactory risk/return levels for the operator. It also is intended to point out particular risk/return characteristics that particular risk/return characteristics that would be unacceptable to the operator.

STANDARD FINANCIAL THEORY
Standard financial theory basically assumes that sources of funds employed by a firm can be classified as either equity or debt. Although this theory recognizes that variations of debt and equity exist, the analytical approach generally applied is to convert these "nonstandard" forms of financing into an equivalent debt or equity amount.
The use of fixed return securities, i.e., debt or its equivalent, results in the creation of "financial leverage." Just as a fulcrum is present when leverage is considered in present when leverage is considered in mechanics, the fulcrum involved with financial leverage is the fixed, after tax, payment required on these securities.
A Modeled Promotional Prospect for Devonian Shale Production
Authors: Plaster Jerry 
Published: December 2007

Abstract
A promotional possibility for a low producible but dependable gas reservoir such producible but dependable gas reservoir such as the Ohio shale is modeled and discussed. This involves the promotion of natural gas availability as part of a planned residential community cooperative. The requirements for success are outlined. Actual performance and return is not dependent upon the examples used. Other reservoirs and other areas can be applied to the model. Exploration, completion and servicing costs are included in the price of building sites and administered through a community cooperative. This affords the contractor a short term payout and long term operation through service contracts if desired. Drilling supplies may be on site or remote from the development. Storage, modes of investment, mechanics of a cooperative and a balance sheet example complete the discussion.

Introduction
Oilfield promotion has suffered recently in two ways, both of which tend to dry up investment money. First, the mistrust of the industry by investors and second, political interference. Combining investment political interference. Combining investment programs may be a solution-to free up capital programs may be a solution-to free up capital and increase domestic energy supplies by examining previously uneconomical gas reservoirs.

MODEL
The model for examination is a real estate development of new high quality homesites with cooperative ownership and operation of gas supplies included in the purchase price. This affords the homeowner purchase price. This affords the homeowner with a guaranteed supply of a presently preferred energy source and the investor with preferred energy source and the investor with a choice of short term return with gas exploration investment or long term in real estate building investment.

CRITICAL ASSUMPTIONS
To establish this working model a number of necessary assumptions must be made:The natural gas situation of limited availability and/or increasing price remains significantly unchanged, i.e., little or no possibility of massive new domestic supplies and/or a significant lowering of retail price.In the proposed area, the availability of over 100 acres at fair market price.
ERDA Research in Fracturing Technology
Authors: Komar C.A. 
Published: December 2007

Abstract
Research in fracturing technology for the ERDA organization is structured on (1) the development of new concepts for increasing the deliverability of natural gas from resources that are classified as marginal by present day practices and (2) the testing and transfer of practices and (2) the testing and transfer of new technology to the private sector. The program at the Morgantown Energy Research Center program at the Morgantown Energy Research Center is centered about their foremost expertise in delineating and utilizing natural and induced fracture systems for enhancement of resource recovery. More recently, the research program has been expanded to include studies of foam fracturing, production history from fractured wells, cost/effectiveness of stimulation treatments and fracture mechanics as support activities for field demonstration projects. The program at the Bartlesville Energy Research Center evolves about their broad experience in stimulation technology in the marginal gas resources of the western U.S. This experience includes nuclear, explosive and more recently, massive hydraulic fracturing stimulation technology.
The ERDA organization interfaces with industry in field demonstration projects of new stimulation concepts that are potentially attractive as techniques for improving the deliverability of gas from known marginal resources. The most widely tested concept to date is the development of massive hydraulic fracturing technology utilizing new fracturing fluids and large volumes of fluid and sand to create long propped fractures. A second noteworthy concept that merits consideration as a future demonstration project includes the utilization of natural and induced fracture systems in conjunction with slant hole drilling and multiple hydraulic fracturing. Together with explosive fracturing and recompletion technology, these concepts offer the best potential for increasing the natural gas supply.
Demonstrations of field worthy technology are conducted with direct service contracts or with cost sharing government-industry contracts both of which are approaches now being pursued. ERDA participation is to provide an interface for technical contributions to the efforts and for the transfer of new technology to be accomplished. Upon successful demonstration of new stimulation techniques, it is anticipated that rapid commercialization will follow.
Performance and Unitization of the Empire Abo Pool
Authors: Christianson S.Hugh 
Published: December 2007

Abstract
Voluntary Unitization of 97% of the Empire Abo Pool, Eddy County, New Mexico, went into effect October 1, 1973. A reservoir study had shown that Unitization would mean recovery of an added 30 million barrels of oil. This would result from aiding the natural gravity drainage by shutting in high gas-oil ratio wells and returning available plant residue gas to the secondary gas cap. A later study showed further improvement in rates and recoveries by drilling additional development wells in low gas-oil ratio areas. Continuing engineering analysis and an aggressive attitude by the Unit owners has resulted in substantial increases in oil recovery and productivity as compared to continuation of productivity as compared to continuation of competitive primary operations.

Introduction
The Empire field is located about eight miles southeast of the city of Artesia in Eddy County, New Mexico (Fig. 1). The discovery well for the Empire Abo reservoir was the Amoco-Hondo Oil Company - Malco "A" No. 1, completed at what is now the Unit M-14 location (Fig. 2), in November 1957. Development moved rapidly to the west, east, and north from the discovery, which proved to be only one location removed from the fore-reef edge of productive limits of the reservoir. Within three years some 215 of the eventual 250 producing wells had been completed. In defining producing wells had been completed. In defining the reservoir, 29 dry holes were also drilled. Field performance before and after unitization is shown in Figures 3 and 4.
Current pool producing rate for November 1976 is 41,700 BOPD, with the ARCO-Empire Abo Unit producing 41,062 BOPD of that total. Unit gas production in November was 55,746 MCFPD. Unit injection into the Abo gas cap in November was 34,451 MCFPD.
Atlantic Richfield Company, with 34.14% interest, operates the Unit for the 112 working interest owners.
The Physical Basis Of Darcy's Law And Its Importance In The Exploration And Production Of Petroleum
Authors: Hubbert M. King 
Published: December 2007

The systematic application of fluid mechanics to the problem of extracting petroleum from underground reservoirs was begun during the decade of the 1920's, and soon thereafter the equation
(1)
which purported to describe the flow of any homogeneous fluid in a porous solid medium, and was attributed to the French engineer Henry Darcy, came into general use as the fundamental flow equation of the petroleum industry for underground fluids. This equation asserts unequivocally:that all fluids flow in a direction perpendicular to the surfaces of constant pressure and in the direction of pressure decrease,that in the same pressure field all homogeneous fluids would flow at each point in the same direction, andthat if the fluid is at rest—a special case of a fluid in motion— the fluid pressure in three-dimensional space must be constant.
However, the third of these propositions violates the known facts of hydrostatics; the second the known fact that diverse reservoir fluids, such as water, oil and gas, migrate in divergent directions and tend to become segregated; and the first can easily be violated experimentally in any desired manner. Hence, the use of this equation in reservoir engineering can hardly have produced any but inhibitory effects in the attempts to understand what really occurs during the exploitation of a petroleum reservoir.
Returning to first principles, and incidentally to the original Darcy experiment, one finds that the flow of a homogeneous fluid through an isotropicporous solid can be described by the equation
(2)
in which is the volume of the fluid crossing unit area normal to the flow-lines in unit time, E is the force per unit mass exerted by the environment on an element of the fluid at a given point, and sigma is a fluid conductivity parameter.
Further examination shows that
(3)
and hence is the vector sum of two separate forces per unit mass, one due to gravity and the other to the gradient of the pressure. In general, these have independent directions. Also,
(4)
Hydrodynamics in the Queensland Sector of the Cooper/Eromanga Basins: Identifying Non-Conventional Exploration Plays Using Water Pressure and Chemistry Data
Authors: Webster M. A. , Grimison A. G. , Brew J. 
Published: December 2007

Abstract
Analysis of water chemistry and pressure data from the Queensland sector of the Cooper and Eromanga Basins indicates that two regional fluid flow systems are operating within these basins. In the Eromanga Basin (Jurassic-Cretaceous) a southwestward and descending open flow system is evident, driven by the topographically induced Great Artesian Basin hydrodynamic regime. In the underlying Cooper Basin (Upper Carboniferous-Triassic) a closed system is reflected by overpressuring and ascending flow out of each of the major Permian troughs. Where the two systems interact and equilibrate, mixing of formation waters from Permian and Jurassic reservoirs is apparent in water chemistry data and potentiometric surface minima can be identified in vertical pressure profiles.
The water chemistry and pressure data have been used to identify hydraulic baffles within the Permian and Jurassic sequences. These barriers are likely to provide effective lateral or vertical seals and, once identified, can be targeted in regional mapping projects to identify potential stratigraphic traps. In addition to the potential exploration applications, regional hydrodynamic databases are also valuable in petrophysical evaluations, by providing estimates of water resistivity in areas with poor well control, and for estimating field limits when the only available pressure data are from hydrocarbon columns within crestal wells.
Effective Permeability Estimation for Simulation of Naturally Fractured Reservoirs
Authors: Nakashima T. , Sato K. , Arihara N. , Yazawa N. 
Published: December 2007

Abstract
Appropriate modeling of naturally fractured reservoirs is one of the most important and challenging issues in reservoir characterization. In simulation, a double porosity or dual permeability model is applied when fractures are well developed to form a fracture network. On the other hand, the single-continuum approach, where the fracture system is represented by effective permeability, is commonly used if fractures are discrete or disconnected. Focusing on the latter case, this paper proposes a semi-analytical technique to evaluate effective permeability for periodically or randomly fractured media including infinitely thin, infinite-conductivity fractures.
The complex variable boundary element method is used to compute potential and stream functions in the two-dimensional space for discretely distributed fracture system under the periodic boundary conditions. Effective permeability is evaluated first for discrete fracture systems of regular patterns as well as a single inclined fracture to demonstrate the validity of the method. 500 distributions of stochastic fractures are next generated to establish correlation between effective permeability and the fracture statistics, i.e., total length L, mean length m, and standard deviation of fracture length σ. Sensitivity to the parameters shows that the incremental gain of effective permeability is proportional to L, that the larger m, the larger effective permeability, and that non-zero σ increases effective permeability. The effective permeability tensors are also determined for oriented fractures. Analyses by non-parametric regression show that the diagonal elements, kxx and kyy are highly affected by the angle between the oriented fractures and the pressure gradient, while the off-diagonal elements kxy and kyx are strongly affected by both the total length and the angle.
Case Study of Hydraulic Fracture Completions in Horizontal Wells, South Arne Field Danish North Sea
Authors: Cipolla C. L. , Berntsen B. A. , Moos H. , Ginty W. R. , Jensen L. 
Published: December 2007

Abstract
This paper provides a case history of hydraulic fracture completions in horizontal wells in the South Arne Field, Danish North Sea (9500 ft TVD, chalk formations).1 The first three propped fracture treatments attempted in the South Arne Field "screened-out" very early in the design due to excessive fracture complexity and fluid leakoff. A detailed study of the rock mechanical properties, wellbore stress & fracture initiation characteristics, far-field stress regime & fracture orientation, and fluid leakoff behavior was integrated with fracture modeling studies to evaluate this problem.2 These studies were used to improve the fracture treatment strategy for future wells, resulting in essentially 100% success placing the designed proppant volumes and achieving aggressive tip screen-outs (TSOs) on over 60 fracture treatments.
This paper summarizes the initial fracture treatment problems and provides a detailed discussion of fracture modeling and design issues, mini-frac analysis procedures, and the mitigation and evaluation of fracture complexity.
Case Histories of a Horizontal Well in the Fissured Mudstone Formation of Daqing Oilfield
Authors: Bi Xueliang , Tie Yan , Zhang Shurui , Fan Sen 
Published: December 2007

Abstract
In the mudstone formation with longitudinal cracks in Daqing Oilfield in northeastern China, there were oil and gas shows in vertical exploratory wells with low yield. A horizontal explor- atory well was drilled through sets of cracks to increase flow area and individual-well producing rate, and the distribution of cracks could be clarified, so the exploration domain can be opened up. Mudstone is unstable, which may lead to serious drilling problems such as wall collapse, well control problems and drill stem sticking, and drilling experience of horizontal well in fractured mudstone is scarce all over the world. The well is the first horizontal well drilled in the fractured mudsto- ne in China. The well was successfully finished with depth of 3,192.00m, the horizontal segment of 1,001.50m. Although well path control in fissured mudstone is difficult, the well trajectory is satisfactory with the geosteering technique. The formation is complicated and dangerous, but there was no serious drilling accident. Drilling fluid is one of the key fact- ors in the drilling, so the properties of drilling fluid was caref- ully maintained, and torque and drag problems were aoided. The well was successfully completed with screen pipes.
The paper describs the main technical challenges, the drilling and cementing processes, and experiences and lessons learned from the construction. A multi-discipline project team was established consisting of geology, exploration, drilling, logging, cementing and completing personnel, which is a key factor leading to the success of the well.
A Parametric Study of Variables Affecting the Coupled of Fluid-Flow/Geomechanical Processes in Stress-Sensitive Oil and Gas Reservoirs
Authors: Guerrero Habib J. , Osorio Jose G. , Teufel Lawrence W. 
Published: December 2007

Abstract
Modeling of coupled fluid-flow/geomechanical processes in stress-sensitive reservoirs has shown that different reservoir conditions yield different degrees of reservoir productivity reduction. Factors affecting the productivity of stress sensitive reservoirs include reservoir permeability, initial loading, aspect ratio, mechanical and physical properties of the reservoir and its surroundings, and fluid compressibility. The effects and interaction among these factors is complex and needs to be investigated if reservoir management is to be optimized.
This study applies the statistical technique factorial design to investigate systematically and efficiently the interactions and effects that the above mentioned factors have on productivity index and cumulative production. To achieve these objectives, this study applies a 3D, finite difference, fully coupled, fluid-flow/rock deformation model.1 The model considers an inner and an outer domain representing the reservoir and its surroundings, respectively. The system is treated as a poro-elastic medium consisting of a deforming solid skeleton and a moving compressible pore fluid. Non-linear elastic deformation is assumed.
Results indicate that the most important variables affecting reservoir productivity and cumulative production are reservoir permeability, aspect ratio, Young's modulus of the inner domain and fluid compressibility (the effect of fluid compressibility and Young's modulus of the inner domain are of the same order). This paper provides a deep discussion on the effect of these factors on both response variables: productivity index and cumulative production
Application of Development Seismic to Infill Technique in Oilfield of Small Size of Sand Body
Authors: Fang Baocai , Wang Qingguo , Xu Hongxia 
Published: December 2007

Abstract
This paper proposes a new approach to infill and adjustment using 3D high-resolution development seismic in blocks which have a complicated structure, smaller sand body and discrete distribution. A detailed description of this structure was interpreted by a full 3D interpretation after effective acquisition of data (bin 10*20m, sampling rate 1ms). Reversion, including wave impedance, laterolog 3 resistivity, spontaneous and natural gamma was done by the application of a thin interbed seismic inversion method. By integrating geological information, logging and production testing, as well as production behavior data, the distribution of the sand bodies was clear and a potentially profitable area of remaining oil was determined. Good results in infill and adjustment were achieved and production in the area was improved.
State-of-the-Art in Hydraulic Fracture Diagnostics
Authors: Cipolla C. L. , Wright C. A. 
Published: December 2007

AbstractThis paper details the state-of-the-art in applying both conventional and advanced technologies to better understand hydraulic fracturing and improve treatment designs. The initial portion of the paper describes the application and limitations of various diagnostic tools and methods, including well testing, net pressure analysis (fracture modeling), techniques that employ open-hole & cased-hole logs, surface & downhole tilt fracture mapping, microseismic fracture mapping, and production data analysis. The bulk of the paper is dedicated to case histories that illustrate the application of these various fracture diagnostic technologies. The case histories include examples of how several fracture diagnostics can be used in concert to provide more reliable estimates of fracture dimensions and allow better economic decisions.
Dynamic Hedging in a Crude Oil Future Market
Authors: Taki Hidesada , Fujita Kazuo 
Published: December 2007

Abstract
The fluctuation of crude oil price is one of the greatest risks that oil-field operators are faced with. Crude oil is a strategie natural resource, and the range of the price fluctuation is quite wide. To avoid the disadvantage caused by the price fluctuation, operators can use oil-linked bonds, such as a crude oil future and a crude oil option on the market. Swap contract is the portfolio of crude oil futures, which is currently utilized in a static manner. Swap contract is preferred, if one wants to minimize the risk. However, this type of contract cannot respond to the boom of oil price and eventually loses the chance of bonus. In this paper, a dynamic hedging strategy is proposed, which can respond to the boom of oil price. The proposed portfolio changes its components in response to the changes of oil market. The performance of the strategy is assessed by using the real trading history on the New York Mercantile Exchange over the period of ten years.