bluuebunny/crossref_metadata_2025_split huggingface dataset:
High-Permeability Fracturing: The Evolution of a Technology
Authors: Smith M.B. , Hannah R.R. 
Published: June 2014

Abstract
Since its introduction almost 50 years ago, hydraulic fracturing has been the prime engineering tool for improving well productivity, either bypassing near wellbore damage or actually stimulating performance. Historically (and in many instances erroneously) the emphasis for propped fracturing was on fracture penetration or length, culminating in massive treatments for tight gas sands using several million pounds of proppant with design 1/2 lengths in excess of 1500 feet (460 m). More recently, the importance of fracture conductivity has become appreciated. This has led to exciting "new" applications of propped fractures in better quality reservoirs as illustrated by North Sea wells, stimulations in Prudhoe Bay, and "frac-pack" operations in the Gulf of Mexico and Indonesia.
While better understanding and new technologies are being used today, the actual application of fracturing to higher permeability formations is not new. During early development of fracturing, nearly all applications were for moderate to high permeability zones (since low permeability rock was of little interest at oil prices of $3/BBL).
While tremendously successful at increasing PI, these early high permeability treatments were doing little more than bypassing damage. More recent development of improved, artificial proppant, cleaner fluid systems, and new technologies have changed this, making it possible to truly alter reservoir flow and stimulate production from moderate to high permeability reservoirs. The primary new tool in the engineers arsenal is the development of "tip screenout" fracturing. While higher permeability formations provide the "new" applications, the actual philosophy shift for fracturing occurred with the massive, tight gas stimulations. while outwardly a traditional, straight forward, application of fracturing to poor quality reservoirs, in actual fact these treatments represented the first engineering attempts to alter reservoir flow in the horizontal plane.
Guntong Field: Development & Management of a Multi-Reservoir Offshore Waterflood
Authors: Chik Amran Nong , Elias Mohd Rohani , Selamat Samsuddin , Wakatake M.T. , White J.P. 
Published: June 2014

Abstract
The Guntong field, the largest waterflood field in offshore Peninsular Malaysia, with an oil-in-place of about 200 mstkl, has been producing since 1985. The field contains 13 stacked reservoirs having small gas caps and limited aquifer support. This paper describes some of the significant reservoir, as well as geologic and facility, challenges faced during development and management of this complex reservoir system. A combination of five-spot and peripheral waterflood patterns was selected to provide the required areal coverage with commingling of reservoirs into two operational groups. Several key reservoir management strategies to maximize performance are: determination and application of optimum target reservoir pressures, development and use of a PC based program and other analytical tools to guide production and injection targets, meeting pattern balancing objectives by implementation of comprehensive reservoir surveillance activities and capacity enhancement programs. To date, the response to the reservoir management efforts has been favorable with an all-time high production rate of 14 kstkl/d having been recorded in 1994.

Introduction
The Guntong field is located in the South China Sea, 210 km off the east coast of Peninsular Malaysia (Figure 1).
Estimating and Reducing Company Wide Property Abandonment Costs
Authors: Johnstone J. E. , Neuser J. M. , Fritts J. M. 
Published: June 2014

Abstract
Many domestic oil and gas properties and production facilities are at the end, or rapidly approaching the end, of their useful economic lives. Corporate management is becoming increasingly concerned with the costs associated with the abandonment of these properties and their potential impact in long range planning scenarios and property evaluations. Abandonment and environmental remediation costs are generally expected to rise in the future due to increased regulation and more rigorous clean-up standards. Identifying these costs and raising management's awareness of these costs in today's operations will help management plan for this approaching problem and generate ways to reduce those costs. The paper describes the steps necessary to organize and manage a successful abandonment and remediation cost study of company wide magnitude. Areas discussed include organization of the review teams, field data gathering, determination and application of historical cost data, and actual cost estimation. The paper presents typical results of the study for various types of production fields facilities as well as ideas for actions today to reduce future abandonment and remediation costs.
Case Study: Natural Attenuation of Dissolved Hydrocarbons at a Former Gas Plant
Authors: Admire J. D. , de Albuquerque J. S. , Cruze J. A. , Piontek K. R. , Sale T. C. 
Published: June 2014

Abstract
In recent years, interest has grown in biological processes that limit the migration of dissolved petroleum hydrocarbons in groundwater. While the process of biodegradation of dissolved petroleum hydrocarbons in groundwater is generally acknowledged, only a few carefully documented examples exist. Work to date at a former natural gas processing plant provides documentation of natural biodegradation of dissolved hydrocarbon in groundwater as well as insights into the microbiological processes that are most significant at this site.
The Study and Application of the Technique of Single Fluid Water Plugging Using AP4 Polymer in Daqing Oil Field
Authors: Zhi Li , Shuxian Gao , Baohe Tian , Quan Zhou 
Published: June 2014

Abstract
This paper summarizes the composition, principle, properties and field application effects of blocking agent in the technique of singlefluid water plugging using AP4 polymer. Both the laboratory investigations and field application show that the blocking agent has some distinct advantages, such as shallow and firm plugging effect, low cost, simple process and easiness of being removed when necessary.
Theory and Application for Helical Flow of Drilling Fluid in the Annuli of Directional Wells
Authors: Zhang Jingfu , Li Bangda , Liu Yongjian 
Published: June 2014

Abstract
Using the principle of fluid mechanics and the geometnc properties of the annuli in directional wells, the law of laminar helical flow of drilling fluid in eccentric annuli was studied. Analytical solutions of apparent viscosity, velocities, flow rate, pressure drop and the stability parameter are presented. Results of numeral simulations are given. Laboratory smdies and field application in eleven wells of Daqing oil field were used to validate the theory. A method for calculating pressure drop in annuli, which can be used in designing hydraulic parameters of directional wells is given.
Experimental Investigation for Measuring Three-Phase Relative Permeability of Oil, Gas and Water for Daqing Oilfield
Authors: Xianmin Zhou , Qingfeng Yuan , Guifang Liu , Yubao Lin 
Published: June 2014

Abstract
An experimental method for measuring three-phase relative permeability of water, oil, and gas in reservoir core samples has been developed. Water, oil,and gas saturation measurement by microwave-weight technique, relative permeability measurement apparatus and experimental procedures are involved in the method. Three-phase relative permeability of water, oil, and gas for a number of waterwet sandstone core samples has been measured by this method in steady state condition. Experimental results indicate that this method is valid to measure three-phase relative permeability of water, oil and gas.
An Approach to Maintaining & Raising Fracturing Effect at High Water-cut Stage of Lamadian Oilfield
Authors: Jiaqi Wang , Lizhu Yin , Xinde Wan , Yuqin Zhang 
Published: June 2014

Abstract
Since 1980, the oil production of Daqing oilfield has been at high water - cut stage. The rate of oil production has naturally decreased. Research was undertaken to maintain and enhance fracturing effects on oil production, including strengthening the preparation for fracturing and management after fracturing. Properly selecting the wells and zones for fracturing is important. Pre-treatment of injection wells and restoration of reservoir pressure can improve the results of fracture treatments in producing wells. Fracturing techniques were also developed for multiple thin intervals. This paper uses examples from the Lamadian Oilfield of Daqing.
Capturing the Potential for Breakout Performance
Authors: Steinhubl Andrew M.J. 
Published: June 2014

Summary
In the future, strategy will play a bigger role in determining how the shareholder value of petroleum companies will increase compared with the overall share market. Outperforming companies will identify market discontinuities and rapidly and aggressively apply existing and new capabilities to generate advantage business positions.

Introduction
The petroleum industry is facing many downside forces. Oil prices are forecast to be flat in real terms with potential for short-term volatility. Operating costs are experiencing upward pressure from stricter environmental standards and other sources. Traditional basins are mature, so elephant hunters have encountered slim pickings. Access to new markets is constrained and competition is intense. The logical response to these prevailing trends has been restructuring and re-engineering. This has led to reduction in activity, outsourcing, and focusing on core assets and skills.
Beyond restructuring, what opportunities exist in the energy business? Agile and aggressive companies may be able to take advantage of second-order trends and changes. These companies will then be able to break from the pack and outperform the rest of the industry (Fig. 1).

Role of Strategy
A McKinsey study of 30 major industry groupings (Fig. 2) showed that in all but two industries some large companies significantly outperformed their peers over the long term. We deemed a company large if annual revenues exceeded $500 million and considered long term 5 to 10 years. The two industries with no sizable outperformers were electric utilities and petroleum. In these two industries, performance was driven by the structure of the industry.
Despite being structure driven, the petroleum industry as a group at various times has drastically outperformed the Standard & Poor (S&P) 500 in terms of increase in shareholder value (Fig. 3). During the boom years of 1976-80, the industry performed extraordinarily well. Then again from 1987 to 1994, the industry excelled as the companies tapped the value of existing assets by restructuring and re-engineering. However, the role of structure vs. strategy may be changing for the petroleum industry. In the future, we think that the petroleum industry will be more like other industries. Company strategy, not industry structure, will be more critical to performance.
The petroleum industry is mature, but other mature industries have significant outperformers (Table 1). Winning growth approaches from other industries are increasingly applicable to petroleum. Although no traditional large players have met the breakout standard (Figs. 4 and 5), examples of the importance of strategy over structure are already emerging in the energy industry.
Modeling the U.S. Oil Industry: How Much Oil Is Left? (includes associated papers 52599 and 52600 )
Authors: Taylor Paul J. 
Published: June 2014

Summary
A great deal of the literature on U.S. crude-oil supply claims that supplies are rapidly depleting. Newer prediction models have become fairly sophisticated but still lack adequate treatment of the physics of oil production and effects of technology. This paper addresses these issues and develops a model that is much less pessimistic and broader in range.

Introduction
Hubbert,1 who first began publishing his ideas in the 1950's, probably initiated the trend of claiming that supplies are rapidly depleting with the notion that U.S. crude-oil production would behave like a bell-shaped curve (Fig. 1). In spite of his lack of defensible theory, Hubbert used this reasoning to conclude the conterminous U.S. (e.g., not including Alaska) would produce no more than 170 billion bbl. Other, more contemporary, analysts perpetuate this notion with forecasts founded on similar principles.2,3
Four basic factors affect oil production:physics,economics,technology, andthe oil still in the ground.
The model developed here incorporates these factors by use of basic production theory and multivariate regression analysis.
The laws of physics require oil production to decline over time. Eq. 1, which can be derived from these laws, is commonly used to model this decline.4Equation (1)
Proved reserves, Q, are calculated by determining the area beneath this curve over the anticipated life of the production, T. This relationship is shown byEquation (2a)
for large T, andEquation (2b)
for the general case. Note that proved reserves can be approximated by dividing the initial production, qi, by the decline rate, di, if a sufficiently long time interval, T, is assumed. Eq. 2b, for the general case, has been rearranged by solving for the decline rate. This relationship between production, decline rates, and proved reserves is powerful for several reasons.
Second-Generation Synthetic Drilling Fluids
Authors: Friedheim J.E. 
Published: June 2014

Distinguished Author Series articles are general, descriptive representations that summarize the state of the art in an area of technology by describing recent developments for readers who are not specialists in the topics discussed. Written by individuals recognized as experts in the area, these articles provide key references to more definitive work and present specific details only to illustrate the technology. Purpose: to inform the general readership of recent advances in various areas of petroleum engineering.

Summary
At the start of the 1990's, three synthetic materials were introduced:esters, ethers, and polyalphaolefins (PAO's). Now heading toward the last half of this decade, a new generation of synthetics is gaining popularity - linearalpha oletins (LAO's), internal or isomerized olefins (IO's), and linearparaffins (LP's). While similar, they also have differences, both as base fluids and as formulated drilling muds. These second-generation synthetic-based fluids (SBF's) have benefits over their predecessors in that they have lowerkinematic viscosity and are less expensive. As drilling fluids, these technical advantages give rise to a more flexible fluid to meet greater drilling demands for high-temperature/high-pressure (HTHP) applications, extended-reach-drilling projects, and deepwater drilling. As with the first-generation materials, environmental issues are the drivers for the development and use of these second-generation synthetics.

Introduction
Drilling with synthetic-based muds (SBM's) or pseudo-oil-based muds (OBM's)has become commonplace in both the Gulf of Mexico and North Sea areas. Synthetics also are in use or their implementation is planned in numerous other regions, such as the Far East, Australia, Mexico, Continental Europe, South America, and Russia. Because of the evolving marketplace, the view is that the industry has moved to at least the second generation of synthetics or pseudos. The boundary that separates first- from second-generation SBM's is arguably arbitrary but generally is delineated by both the cost and kinematic viscosity of the base fluid. Typically, second-generation synthetics are cheaper and thinner. Even considering these factors, second-generation SBM's have not totally replaced first-generation ones, although the use of the former flourishes while the latter wanes in areas where they coexist. Therefore, the first-generation SBM's can be considered to be based on the ester, ether, and PAO, while in the subsequent generation, the LAO's, IO's, and LP's are the base materials. Table 1 gives a more complete listing of first- and second-generation synthetics.
The Importance of In-Situ-Stress Profiles in Hydraulic-Fracturing Applications
Authors: Hopkins C.W. 
Published: June 2014

Technology Today Series articles provide useful summary information on both classic and emerging concepts in petroleum engineering. Purpose: To provide the general reader with a basic understanding of a significant concept, technique, or development within a specific area of technology.

Summary
In-situ stresses define the local forces acting on lithologic layers in the subsurface. Knowledge of these stresses is important in drilling, wellbore-stability, and, especially, hydraulic-fracturing applications. The measurement of in-situ stress is not straightforward and, therefore, often goesunmeasured. As such, we often assume values of in-situ stress or estimate in-situ stresses from logging parameters. This article illustrates the importance of in-situ-stress estimates as they relate to hydraulic fracturing and outlines several techniques for estimating in-situ-stress magnitudes.

In-Situ Stress
The in-situ stresses acting on a formation can be decomposed into three principal compressive stresses, one vertical and two horizontal. The two horizontal compressive stresses are usually not equal. The vertical stress is caused by the overburden weight acting on the top of a formation. The horizontal stresses are the result of the poroelastic deformation of the rocks plus externally applied tectonic forces. The parameters that affect the magnitude of the in-situ stresses include overburden weight, fluid porepressure, porosity, anomalies in the rock fabric (i.e., natural fractures), rock mechanical properties (such as Poisson's ratio), and tectonic activity.
Knowledge of the in-situ-stress magnitude and direction can impact decisions and designs throughout the drilling and completion of a well. During drilling, in-situ stress may affect the mud and cement densities required to prevent unwanted fracturing of openhole strata in the wellbore. For wells that will be stimulated at high pressures, casing design must account for the maximum anticipated stresses. Wellbore-stability calculations, particularly for horizontal wells, require knowledge of in-situ-stress magnitude and direction.
For hydraulic-fracture treatment applications, the in-situ stresses control fracture azimuth and orientation (vertical and horizontal), fracture-height growth, fracture width, treatment pressures, and fracture conductivity. As Fig.1 illustrates, fractures grow perpendicular to the minimum in-situ-stress direction; thus, stress direction can affect well-placement and -spacing decisions.
Acoustic-Velocity Signatures Associated With Rock-Deformation Processes
Authors: Scott T.E. , Zaman M.M. , Roegiers J-C. 
Published: June 2014

Distinguished Author Series articles are general, descriptive representations that summarize the state of the art in an area of technology by describing recent developments for readers who are not specialists in the topics discussed. Written by individuals recognized as experts in the area, these articles provide key references to more definitive work and present specific details only to illustrate the technology. Purpose: to inform the general readership of recent advances in various areas of petroleum engineering.

Introduction
The petroleum industry is increasingly involved in producing oil and gas from problem reservoirs, which typically are those reservoirs susceptible to large deformations and compaction during recovery operations. These problem formations have high porosities, high pore pressures, are poorly consolidated, or are highly fractured. In many cases, production operations can lead to drastic, irreversible damage to these reservoirs.
Rock formations can undergo deformation by a wide variety of mechanisms, including dilatancy (precursory to tensile or shear failure), pore collapse, and normal consolidation. In particular, pore collapse and normal consolidation can lead to significant production problems, such as loss of permeability, surface subsidence, and collapse of boreholes. For example, the Ekofisk Field in the North Sea has undergone significant subsidence (more than14 ft) as a result of the extraction of oil and gas. The Groningen gas reservoir in The Netherlands is another example of subsidence induced by hydrocarbon extraction, and the Lagunillas field along Lake Maricaibo in Venezuela has experienced both compaction and subsidence.
Dramatic changes in mechanical rock damage are accompanied by significant changes in acoustic velocities. This suggests that such techniques as four-dimensional (4D) -seismic surveys [i.e., repeated three-dimensional (3D)surveys] or crosswell tomography can be used for detection and time-lapsemonitoring of rock-deformation processes in oil and gas reservoirs. In this paper, we review the various processes that cause rock damage and investigate the acoustic detection of the deformational processes.
Two distinctly different types of laboratory experiments have been conducted to examine changes in acoustic velocities in porous carbonate rocks. The first involves recording acoustic-wave velocities in both the axial and lateral directions of samples of both Cordoba Cream limestone and Ekofisk chalk deformed during standard triaxial-compression, uniaxial-strain, and hydrostatic compression tests. The second type of experiment presents a new technique (and technology) for acoustic imaging of rock deformation in a high-pressure triaxial cell. The technique uses compressional-wave velocities to image tomographically the localized pore collapse damage created in a confined-indentation experiment.
Impact of Production-Sharing Terms on Investment-Community Performance Statistics
Authors: Young E.D. , McMichael C.L. 
Published: June 2014

This paper (SPE 52017) was revised for publication from paper SPE 49178, prepared for the 1998 SPE Annual Technical Conference and Exhibition, New Orleans, 27 30 September. Original manuscript received 17 June 1998. This paper has not been peer reviewed.

Summary
Hydrocarbon reserves and the ability to produce them profitably are the lifeblood of the upstream petroleum industry. Aggressive competition, ever-sharpening scrutiny by the investment community, and volatile product prices drive companies to search for attractive new E&P venture opportunities that will add the greatest value for a given investment. Production-sharing and other related nontraditional agreement types have become popular because they provide host countries with the flexibility to tailor fiscal terms to fit their sovereign needs. However, actual agreement terms, including those that relate to royalty payments, cost recovery, profit sharing, and taxes, can have a significant impact on the statistics that the investment community uses to access and rank the performance of a petroleum company. This paper examines the impact of these terms and of product-price volatility on investment-community performance statistics, such as reserves replacement; unit exploration, development, and operating costs; and earnings. Representative examples demonstrate the variation in these performance statistics with variations in product price. Limitations in the various indicators are highlighted.
P. 50
Liberalization of European Gas Market
Authors: Kavoussi Fariborz 
Published: June 2014

Abstract
This paper deals with a stepwise approach on the liberalization of the European gas market.
It commences by giving an overview in the current situation in the European gas market countries as well as the gas supply countries. The EU gas directive is being discussed with close look at gas unbundling, stepwise market opening for customers and take or pay contracts.
The UK gas market is described after ten years of liberalization and a comparison made between US and EU gas market. Also gas pricing in a liberalized EU market is being assessed.
Consecutively a few cases will be assessed, taking into account the EU gas directives and its implementation on the EU gas industry.