bluuebunny/crossref_metadata_2025_split huggingface dataset:
Fractured Reservoir Characterization Using 3D AVD
Authors: Pan Renfang , Li Mei 
Published: December 2007

Abstract
Fracture, especially the directional fracture genetic with structural stresses, characterizes anisotropy and orientation to fractured reservoir, which can be detected by 3D AVO analysis.
AVO, amplitude variation with offset, conventionally is applied to detect hydrocarbon reservoir, especially gas bearing sands due to its Poisson’s ratio changes that constantly related with the status of in-situ saturation of hydrocarbon. Shuey’s function formulates dual available parameters – intercept P and gradient G, their imparity reflects the differential combination of lithology, petrophysics and hydrocarbon saturation. Consequently, at a specific point of fracture zone, anisotropy of strata would cause discrepancies of P & G values between different directions horizontally, this would be significant to structural fracture and gain maximum at conjoint set perpendicular to and parallel to fracture orientation. Therefore, vector analysis of AVO parameters from 3D AVO methodology leads to detail interpretation of fracture spacing and density.
The Reservoir Prediction And Gas Indication of Two Gas-Beaing Structures in CD Basin
Authors: qin Fengrong 
Published: December 2007

Abstract
This paper will summarize the methods of reservoir prediction and gas indication of structures TJ and YK with a sandstone reservoir on the beach-shallow lake facies—lake basin bog facies at the Quaternary age in the CD basin. It provides an effective technical system for solving the problems of a distinguishing reservoir from other kinds of rock and distribution of the formation containing gas, a thin layer and complex reservoir rock, and the unreliable seismic data because of the layer of gas. The results show that the exploration idea should be the complement of the lithology element. In addition to the idea of finding a structure for gas, the saddle zone between the two structures may be a potential area located in the zone of sandstone development deposited on the river-channels under water during the Quaternary.
Evaluation on Results of Multiple Infilling & Adjustment in Sazhong Area
Authors: Guo Wankui , Yan Yaru , Liu Bing , Liu Qi 
Published: December 2007

Abstract
This paper conducts analysis on problems occurred during the development of Sazhong Area in Daqing Oilfield such as small reserve controlled by basic well pattern, low ultimate recovery efficiency, etc. It introduces the solution of infilling adjustment, analyzes and evaluates on full scale various production indexes like production rate, formation pressure, control degree and production situation of different formations, effect in old wells, and ultimate recovery efficiency, etc. after each infilling adjustment. Result shows that recovery efficiency can be improved by 6–8% after primary infilling adjustment, 4–5% to 45.5% after secondary infilling adjustment, and to 47.48% after tertiary infilling adjustment. It was realized that only when certain well pattern density was reached through reasonable division of formation series and multiple infilling adjustment, can we improve the control degree of various kind of formations and the ultimate recovery efficiency, and develop the continental heterogeneous reservoir with high efficiency and high quality.
The Research and Application of Assistant Decision System for Economic Development and Production in Tarim Oilfield
Authors: Jiang Tongwen , Longde Sun , Lian Zhanggui , Hu Haidong 
Published: December 2007

Abstract
With the inner oil market joining up the world market and the establishment of oil company, the developmental target is changing from yield to economic benefit. According to the balance theory of profit and loss, the Assistant Decision-Making System for Economic Development and Production in Tarim Oilfield has been developed. It has four subsystems: the well open/shout-down assistant decision-making subsystem (the economic minimum yield, the economic maximum water cut); the well stimulation assistant decision-making subsystem (the economic minimum oil increment); the infill development assistant decision-making subsystem (the economic pattern arrangement), and the production benefit evaluation subsystem (the benefit evaluation, objective cost, target yield). This system have is characterized by reliability, flexibility and visualization for use by on-the-spot engineer. It can make a fitted combination of economic evaluation to engineering and of production to market.
An Experimental Approach to Prediction of Asphaltene Flocculation
Authors: Wang J. X. , Buckley J. S. 
Published: December 2007

Abstract
Many of the existing models that have been developed to predict the onset of asphaltene flocculation rely on approximations to a full thermodynamic treatment of asphaltene phase behavior and on parameters that are not available except by fitting HTHP data to the model. A much simpler approach has been developed based on experimental measurements of refractive index (RI) at the onset of flocculation for precipitants representing a range of molecular sizes.
The onset of asphaltene flocculation is often reported in mixtures of oil, solvent, and asphaltene precipitants. In this work, direct measurements of RI replace estimates of solubility parameters. RI is readily measured and is a good indicator of the ability of the oil to maintain a stable dispersion of asphaltenes. Tests with stock tank oil samples have shown that there is a common trend relating RI at the onset of instability to precipitant molecular size. This observation facilitates predictions of asphaltene instability for a wide range of conditions from as few as one or two onset determinations with precipitants of known molecular size. Results obtained at ambient conditions for stock tank oil can, in principle, be extended to reservoir conditions using standard PVT and compositional data, as demonstrated in this paper.
Corrosion Testing of Inhibitors to Protect Welds against Slug Flow in Deepwater Conditions
Authors: Skogsberg Lillian A. , Miglin Bruce P. , Ramachandran Sunder , Bartrip Keith A. 
Published: December 2007

Abstract
Corrosion inhibitors are used to protect deepwater facilities against internal corrosive attack. This can particularly occur in the slug flow regime. In this article, the testing of corrosion inhibitors to protect against slug flow in deepwater locations is described. A testing protocol for corrosion inhibitors that evaluates the corrosion performance of weld metal, the heat affected zone (HAZ) and the base metal in the appropriate flow regime is described. A description of other compatibility requirements is also given.
Performance Improvements from Chemical Drag Reducers
Authors: Campbell Samuel E. , Jovancicevic Vladimir 
Published: December 2007

Abstract
For over 20 years, high molecular weight polymers and surfactants have been used to reduce pressure drop and enhance flow in oil and aqueous systems from production pipelines to water injection systems. The mode of action has been attributed to a reduction in energy loss by a suppression of turbulent fluctuations. However, surface modifications also play a role gas transmission systems. As will be shown with laboratory and field data, the alteration either in the surface or in the fluid flow properties can also improve other aspects of oilfield production. Such as in this paper, four particular instances of drag reduction will be related to corrosion performance. In a first case, two model surfactant corrosion inhibitors, cetyltrimethylammonium chloride (CTAC) and cetylpyridinium chloride (CPC) were chemically modified to drag reducing agents by exchange of the chloride with salycilate counterion. The modified surfactants (cation exchanged) and the corresponding halides were compared in a corrosion test under conditions were drag reduction occurred. Drag reduction promoted corrosion inhibition in a standard corrosion test. In a second case, the introduction of a low foam surfactant into a brine system resulted in a reduction in the corrosion rate as shown by laboratory data. In a third case, utilizing a cleaner/antifoulant surfactant, the pressure drop was reduced and the production increased in a gas gathering system. As a side benefit of the removal of solid deposits, the uninhibited corrosion rate was decreased by a factor of seven. In a final case, a foaming surfactant was utilized to remove liquid hold-up in a production well. By removing the liquid hold-up, the corrosion rate was decreased. Utilizing a drag reduction chemical in an oil or gas production system can lead to additional performance enhancements as demonstrated for the case of corrosion control.
A Summary of Successful Field Applications of A Kinetic Hydrate Inhibitor
Authors: Fu S. B. , Cenegy L. M. , Neff C. S. 
Published: December 2007

Abstract
A kinetic hydrate inhibitor based on a copolymer of vinylcaprolactam and vinylmethylacetamide has been successfully deployed in a number of fields, including both inland and offshore applications. The inhibitor has a low toxicity and manages a high degree of subcooling, up to 20°F. The effective dosage ranges from 550 ppm to 3000 ppm, depending upon the severity of the operating condition in each field. The performance of this inhibitor, the field conditions in which it was applied, and the benefits are discussed in this paper. These field cases helped establish the application technology for proper deployment of kinetic hydrate inhibitors. The success of these programs has confirmed the viability of using kinetic inhibitors as an effective hydrate control method. This kinetic inhibition technology not only provides an attractive cost-saving alternative to thermodynamic inhibitors; it also improves the safety of operation while lowering the environmental impact.
Evaluation of Retarded HF Acid Systems
Authors: Al-Dahlan M. N. , Nasr-El-Din H. A. , Al-Qahtani A. A. 
Published: December 2007

Abstract
Stimulation of sandstone reservoirs usually involves the use of a hydrofluoric-based acid (HF). Hydrofluoric acid reacts rapidly with clay minerals and slowly with sand particles. Stimulation of sandstone formations is a challenging task because it involves several chemical and physical interactions of the acid with the formation. Some of these reactions may result in formation damage. Retarded HF (RHF) acids are less reactive with the rock and normally result in deep acid penetration into the formation.
Three RHF acids that are based on boric acid (H3BO3), aluminum chloride (AlCl3), and a phosphonic acid were examined. Several tests were conducted to evaluate interactions between RHF acids and sandstone rocks. Static solubility tests were performed using sand particles and clay minerals at 25 and 75°C. Chemical analysis of spent acids was extensively used in this study.
Acidizing sandstone reservoirs using mud acid is a complex process where dissolution and precipitation occur simultaneously. The process is even more complicated when RHF acids are used. The results of this study indicate that the composition of spent acid strongly depends on the retarded system used. Dissolution of clays is generally reduced when a form of RHF is employed. However, increasing the soaking time caused precipitation in all RHF acids examined. Some of the RHF acids precipitate materials that are not encountered when regular mud acid is used. This paper addresses several chemical interactions that have not been addressed previously in the literature.
Development of New "green" Demulsifiers for Oil Production
Authors: Dalmazzone Christine , Noïk Christine 
Published: December 2007

Abstract
There is an increasing need in the oil production to limit the use of chemicals and to search for safer products, mainly due to more severe environmental constraints. Demulsifiers performance has to be therefore improved, from the application as well as from the environmental point of view. New formulations must be less toxic and at least as efficient as classical chemical families, which contain toxic molecules like phenol groups. A methodology was developed to screen the main chemical families used as demulsifiers. Effective separation ability of different surfactants was first evaluated according to the classical " bottle test". From this preliminary screening, some silicone derivatives appeared to be efficient on several crude oil emulsion types and were therefore studied more intensively. A specific methodology was used, including turbidimetric measurements with a vertical scanner to quantify water and oil separation kinetics and also the quality of the separated water. Finally, silicone chemicals were found to exhibit very interesting performances and could be used as "green" demulsifiers in oil production.
Steering of Horizontal Wells with 3D High Resolution Seismic Model
Authors: Lanfranchi Pierre 
Published: December 2007

Abstract
Until recently, seismic data failed to be used for qualitative reservoir characterization for two main reasons:
the vertical resolution is not good enough to describe the subtle stratigraphic feature at the reservoir scale there is no direct relationship between seismic amplitudes and reservoir related parameters (porosity, permeability, …), fluid content and lithology.
In this paper, we first present an optimized method allowing us to overcome the two drawbacks given above. Then, we will show examples where this technique is successfully applied to steer horizontal drain in order to optimize production performance.
SWAG Injection on the Siri Field - An Optimized Injection System for Less Cost
Authors: Quale Eileen A. , Crapez Bénédicte , Stensen Jan A. , Berge Lars Inge 
Published: December 2007

Abstract
Simultaneous Water And Gas (SWAG) injection has been implemented on the Siri Field on the Danish Continental Shelf and represents the first reported full field application of its kind in the North Sea. The associated produced gas is mixed with injection water at the wellhead, and injected as a two-phase mixture. The required total injection volume for voidage replacement is thus achieved with a simplified injection system, fewer wells and reduced gas recompression pressure requirements.
Injection per well has typically been in the range 4,000–8,000 Sm3/day (25,000–50,000 bpd) water and 200,000 – 400,000 Sm3/day (7 −14 Mscf/d) gas.
Evaluation of alternative injection schemes identified SWAG as the optimum scenario for Siri. The choice reflects that:
There is no established gas export infrastructure in the immediate area, Siri gas volumes alone are too small to warrant establishment of a system, and routine gas flaring is unacceptable. Reinjection is therefore required. Reservoir simulation studies indicate improved oil recovery (IOR) with combined gas and water injection as compared to pure water injection, apparently related to attic oil displacement, reduced residual oil saturation and better sweep efficiency. Continuous water injection from both injectors is required to maintain reservoir pressure.
The SWAG concept fulfills all these requirements, representing a safe, economic and environmentally-friendly development solution.
Production Gains from Re-Fracturing Treatments in Hassi Messaoud, Algeria
Authors: Marquardt Michael B. , van Batenburg Diederik , Belhaouas Rafik 
Published: December 2007

Abstract
Since 1990, over 200 hydraulic fracturing treatments have been performed in the Hassi Messaoud field in northeast central Algeria resulting in an average production increase of 5 m3/hr (750 bopd). The success of the stimulation program in this Cambrian age sandstone formation resulted from improved field practices of treating open-hole and slotted liner completions, and from the use of state-of-the-art fracturing equipment and engineering tools.
After several years of production, the production rates of some fractured wells have declined due to several reasons: reservoir depletion, salt precipitation from formation water breakthrough or injection water breakthrough, and fracture conductivity damage due to barium sulfate scale and asphaltene deposition. Since 1996, re-fracturing treatments have been conducted on nine wells in order to restore production by placing another propped hydraulic fracture in the same target drain.
The three case histories presented show exceptional, normal and marginal responses to the re-fracturing treatments. Explanations for the observed responses are presented and recommendations for the selection of new re-fracturing candidates in the Hassi Messaoud field are presented.
Present Status and Development Prospect of Oilfield Chemicals in China
Authors: Ji-de Liu , Ya-bin Niu , Da-ming Zhang 
Published: December 2007

Abstract
This paper presents the production and applications of a five classes of oilfield chemicals according to "standard of the kind and code of oilfield chemicals" issued by CNPC, and the results gained in oilfield application. Some key oilfield chemicals and oilfield chemicals given priority to development in the near future were pointed out.
Application of Drilling Fluid chemicals in China
Authors: Zhang Daming , Niu Yabin , Liu Jide 
Published: December 2007

Abstract
This paper present the sixteen types of drilling fluid chemicals manufactured in china and describe some important chemicals in detail. The consumption of drilling fluid chemicals is listed on different types for each year. The tendency of consumption of chemicals is analyzed. According to API Classification of drilling fluid and characteristics of Chinese drilling fluid application, drilling fluids are classed in nine types. Explanation and formulations of nine types of drilling fluid are presented in this paper. The recent development of drilling fluids is presented in this paper. The recent development of drilling fluid chemicals and drilling fluid systems is analyzed. The mechanism and formulation of these new drilling fluids are presented. Nowadays, drilling fluid chemicals manufactured in china can satisfy the native market, some of them are exported to abroad market.
Emulsification and Stabilization of ASP Flooding Produced Liquid
Authors: Di Wu , Xiangchun Meng , Fengling Zhao , Ruiquan Zhang , Yan Chen , Qingsheng Wang , Huicheng Liang 
Published: December 2007

Abstract
Emulsification and stabilization of o/w ASP flooding produced liquid in Daqing Oilfield were studied on artificial produced liquid and oily water. The influences of alkaline (NaOH), surfactant and polymer (partially hydrolyzed polyacrylamide HPAM) on the stability of ASP flooding produced liquid and oily water were tested. Bulk phase rheology and interfacial properties such as interfacial tension, oil droplet Zeta potential and interfacial rheology were tested to reveal the mechanisms of the emulsification and stabilization of ASP flooding produced liquid. The experimental results showed that residual alkaline, surfactant and polymer in ASP flooding produced liquid all tend to increase the stability of o/w ASP flooding produced liquid; The emulsification of ASP flooding produced liquid is mainly caused by the reduction of dynamic oil-water interfacial tension by residual alkaline and surfactant, the increase of water-phase viscosity by residual polymer, and the mechanical shear experienced by ASP flooding produced liquid during production; The stabilization of ASP flooding produced liquid by residual alkaline, surfactant and polymer lies in the enhanced emulsification of produced liquid in which smaller oil droplets are produced, the increase of water phase viscosity by polymer which decreases the rising velocity of oil droplet and the hindrance of alkaline and surfactant on oil droplet coalescence.
Remotely Acidizing Satellite Wells
Authors: Da Motta E. P. , Branco C. C. M. , Shecaira F. S. 
Published: December 2007

Abstract
Matrix acidizing of satellite wells in deepwater fields depends on the use of a dynamic position vessel (DPV), what makes it a very expensive operation. Moreover, the availability of DPVs for stimulation treatments can be a limiting factor for deep water and even for ultradeep water fields. For some shallow water fields with particular characteristics, the use of DPVs is also mandatory. While the acid treatments of several satellite wells in the Campos Basin, offshore Brazil, are not performed due to cost restrictions and/or DPV availability, injectivities and productivities of those wells are decreasing. If not properly controlled, these declines could jeopardize the profitability of some fields. One solution for this problem, devised by Petrobras R&D Center (CENPES), consists of anchoring the stimulation boat to the production rig and pumping the acid treatment through the flexible pipelines, which may extend for several kilometers. The main difficulty for performing such a treatment is controlling the corrosion of metallic parts of the pipelines, as well of the Christmas tree and tubing. This paper presents the results of the remote acidizing of an offshore well of the Campos Basin, producing oil from a carbonate reservoir. The paper also describes in detail the laboratory tests required for the field test.
Development of Reserves Booking Guiding Principles for Sound Reservoir Management
Authors: Vikas Shree , Zammerilli Anthony , Ranganathan Raja 
Published: December 2007

Abstract
Reporting of reserves or "reserves booking" is an important issue in reservoir management. Despite this fact it is not practiced in a consistent manner by field operators, royalty owners, the Government, the investing community, and other stakeholders in the oil and gas industry. Furthermore, the Securities and Exchange Commission (SEC) and Financial Accounting Standards Board (FASB) statements on this issue are fairly vague, leaving much to individual interpretation of the rules. This inconsistency in reserves booking is due in part to the lack of a well-defined set of guidelines and is exacerbated by geologic and market uncertainties.
In this paper, we investigate approaches to improve reserves booking procedures making use of the 14th update of NRG Associates database "The Significant Oil and Gas Fields of United States". Data from all the gas fields discovered in the year 1990 were taken to arrive at an average representation of the reserves booking practice. In addition, two fully developed fields in the Rocky Mountain region and the Gulf Coast region were taken to investigate individual field level reserves booking practices.
Our results indicate that reserves booked increases more than linearly as a function of drilling. These results are confirmed by conversations with industry experts and support the conclusion that players in the industry tend to be conservative, delaying reporting of reserves. This is contrasted with the "diminishing returns" concept where there is a large increase in knowledge (i.e. reserves booked) during the initial phase, and then beyond a point, the gain in knowledge is less than proportional to the gain in effort spent (i.e. drilling).
In order to arrive at a compromise "best practice" for booking reserves, we recommend a linear relationship and propose that reserves booked from the field should be directly proportional to the number of successful development wells drilled. This will help in capturing the true Finding and Development (F&D) cost of different basins and their relative competitiveness.