bluuebunny/crossref_metadata_2025_split huggingface dataset:
Transverse Multi-Fracture Technique in Kitina Highly Deviated Off-Shore Wells
Authors: Pace Giamberardino , Casero Alberto , Tealdi Loris , Obondoko Gaston , Rampoldi Maurizio 
Published: June 2014

Abstract
Brownfield field have been defined as mature field in a state of declining production or reaching the end of their productive lives. Nevertheless these fields provide more than 50% of world's production as well as world's reserves and so it will be for next 20 years. For that reason revitalization of mature fields has to be a "must".
The Kitina Field, offshore from Pointe Noire, Congo, is one such field. Deeper sands have been produced to economic depletion and, in order to maintain the economic operation of their valuable assets, alternative production intervals have been opened to production. Most of these low permeability reservoirs can produce at economic rates only with the application of hydraulic fracturing treatments in a multi-fractured well scenario.
Accurate candidate selection, optimized treatment design, sound reservoir modeling of production forecast represent crucial and interdependent factors for successful economic evaluations.
This paper describes the massive hydraulic fracturing campaign carried out between April and June 2007 on the Kitina 3A reservoir, offshore Congo. Eight hydraulic propped fractures were placed in three re-completed, cased-hole highly deviated wells with very encouraging production increases (stabilized production increase ranging from 2 to 3 times). The transverse multi-fracturing technique was adopted. This technique utilizes a series of packers and frac-ports that are sequentially shifted allowing continuous placement of more than one hydraulic propped fracture without shutting down the pumping equipment. All the aspects from candidate selection, pre-job design, on-site operations and post job evaluations with particular focus on the operational challenges encountered are described. Recommendations for the future applications of this stimulation technique are proposed. Furthermore, the challenging theme of forecasting mid-long term production profiles for horizontal, slanted and vertical multi-fractured wells is tackled. Different analytical and numerical models, approaching the task with various methodologies, were applied and tested to define the production profiles of the three candidate wells, which differ in terms of geometry and reservoir properties. On the base of the experience gathered on such wells, some general guidelines were drawn for a wider application.
An Applied Chemical Flooding Simulator and Its Application in Daqing Oilfield
Authors: Chen Guo , Li Ye , Wang Jinmei , Ma Moran , Lu Kewei , Jin Guangzhu , Sun Hongli 
Published: June 2014

Abstract
Daqing Oilfield has conducted various complex chemical improved oil recovery methods in both pilot tests and field applications such as alkali-surfactant-polymer (ASP) flooding, ASP+Foam flooding and multi-polymer flooding, in the meantime, some new process mechanism for various chemical flooding techniques has been rediscovered, for example, polymer elasticity could increase micro-scale oil displacement efficiency, making the existing chemical flooding simulators insufficient to handle these complex chemical flooding process mechanism. In this paper we develop an applied chemical flooding simulator to have capability to simulate various complex chemical flooding processes in Daqing Oilfield. In comparison with existing chemical simulators, the newly incorporated features include the chemical synergistic effect among surfactant, alkali and oil in ASP flooding with ultra-low surfactant concentration, increasing micro-scale oil displacement efficiency by polymer elasticity, multi-polymer commixing flooding process, foam behavior dependent on the reservoir pore structure and the ratio of gas to liquid in foam system, relative permeability that is a function of polymer elasticity and capillary number. The simulator models the other main physicochemical phenomena in chemical flooding process such as convection, dispersion, diffusion, adsorption, aqueous reactions, in-situ generation of surfactant from acidic crude oil, etc.
The solving scheme for the simulator is sequential solution method, deriving pressure equation, saturation equation and concentration equation from mass conservation equation, and then solving the pressure equation implicitly, followed by obtaining the implicit solution of the saturation equation through Newtonian method. For concentration equation, an operator splitting method is employed to split it into a diffusion equation and convection equation, obtaining implicit solution by alternately solving the diffusion and convection equation. The solution procedure for diffusion equation is ADI. The convection equation is discretized using an implicit single point upstream method, by taking advantage of the reservoir flow potential field, to obtain an implicit non-iteration solution algorithm.
The developed model is a 3-D 3-phase (oil, water and gas) and multi-component chemical flooding simulator, having ability to simulate single polymer flooding, multi-polymer flooding, ASP flooding, and ASP+Foam flooding. It has been successfully applied in various chemical flooding simulations. This paper also presents some cases for its application in Daqing Oilfield.
The Convergence of Knowledge Management, Collaboration, and Enterprise Social Computing in the New Learning Organization
Authors: Holloway Sandra 
Published: June 2014

Abstract
Broad industry trends that are reshaping the exploration and production operation—an aging work force, competition for the best talent, generational shift, and increasing business complexity—warrant a rethinking of traditional operating models as part of new digital oil field strategies. New operating models, based on collaborative business processes and specialized operating facilities, link engineers with platforms and fields in remote locations via real-time global networks. These collaborative environments enable energy companies to leverage the collective knowledge and experience of expert practitioners to improve performance and capture maximum benefits from smart oil field technologies. Important capabilities that contribute to the success of new operating models include the operator's ability to shape a new culture of collaboration and teamwork based on trust and knowledge transparency, propagate global communities of expert practitioners, leverage tools and technologies that enable the capture and sharing of knowledge in real-time, and, integrate continuous learning as a strategic organizational capability. Now, next-generation Internet, collaboration and knowledge-sharing technologies are converging to introduce a new class of user-defined, user-driven applications that hold the potential to speed realization of these capabilities across the digital oil field. This paper explores how energy companies can leverage next-generation knowledge management; enterprise social computing; and collaboration technologies, as an integral part of digital oil field information systems, to enhance collaborative decision-making and knowledge sharing; and drive operational excellence.
The Value of Data in Multiple Repositories
Authors: Kozman Jess 
Published: June 2014

Abstract
Recent mergers and acquisitions have produced a trend of selecting "best of breed" applications for exploration and production analysis. The prevailing opinion is that reducing the number of applications and their associated data repositories leads to savings in data management costs. However, an analysis of the actual impact of these shifts in terms of Change Trajectory, as defined by industry studies on threats to core activities and assets, shows that the cost of data transition and change management may outweigh and these advantages. A standard methodology for identifying and analyzing the data repositories and processes used for business critical exploration and production data types shows that there is an optimum complexity of data management infrastructure for any given size organization. The impact of data management processes is measured by value statements created from standardized measures of opportunity cost. Multiple international case studies are used to document a direct relationship between the complexity of data management repositories and processes and the maturity of data management solutions, as measured by an industry standard Maturity Model. These case studies illustrate different Change Trajectories of oil and gas producers and the information management services industry, using examples of client environments where data has been migrated between applications. Analysis of these migrations suggests a roadmap for success in adopting the correct Change Trajectory strategy. Organizations that fail to recognize the correct strategy will lose considerable competitive advantage during the merger and acquisition cycle.
Safety in the Digital Oilfield: A System Integrator's View
Authors: Lasrado Vineet 
Published: June 2014

Abstract
This paper covers different aspects of safe operations and steps organizations can take to use information technology solutions to improve the safety of their operations. Safety alerts, Information management for availability of latest documents and data, safety KPIs and integration of KPIs from different systems, GIS to track a potentially hazardous situation, Maintenance systems are examples of IT solutions for improving the safety of operations. It is also important to integrate multiple systems in order to improve workflow and reduce scope for error due to manual processes. The importance of sharing data on safety and how IT solutions can be used to share data across organizations (via a third party) will be addressed. Several different organizations where incident information is maintained will be mentioned.
Safety of operations is an important aspect of HSSE in the oil and gas industry. Several steps which organizations can take to improve safety will be discussed. These steps help in making data easily available and reducing the time spent in incorporation of Integrity Management programs. Typical results of the impact of certain IT solutions in this paper on safe operations will be discussed (the results are from the literature and not of any study conducted for this paper)
IT Solutions can help in improving safety in the digital oilfield. A variety of solutions to increase the safety of their operations via IT solutions exist. An overall assessment and proper project management of any newly designed system is also required to find any new risks due to the implemented systems as compared with the previous mode of working. Change management is also an extremely important aspect to make any new solution to be adopted successfully in the organization. One of the KPIs has to be to improve the safety of the operations.
Hydrates: State of the Art Inside and Outside Flowlines
Authors: Sloan E.D. , Koh C.A. , Sum A.K. , Ballard A.L. , Shoup G.J. , McMullen N. , Creek J.L. , Palermo T. 
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.

Abstract
The state of the art of three hydrate applications in petroleum engineering is presented in order of decreasing importance:flow assurance,energy resource, andclimate change. In flow assurance, there is a hydrate-plug-prevention shift under way: from avoidance to management of hydrate formation.
In addition to avoiding the region of hydrate stability by injecting thermodynamic inhibitors, time-dependent studies enable flow-assurance engineers to better address such concerns as flowline restarts, cold (stabilized) flow, low-dosage hydrate inhibitors, and plug remediation. These applications are related to conceptual ideas of hydrate-plug formation in oil and condensate systems. The second area, energy resources, is marked by a transition to an extended production test in the permafrost, and to characterizing resources and economics in the marine environment. The third area, climate change caused by hydrates, is an area of current research. Preliminary estimates suggest no abrupt methane contribution to the environment from hydrates in the immediate future.

Introduction
Natural-gas hydrates (clathrates) are crystalline, ice-like solids that form when small (&lt;9 Å) molecules contact water at low temperature and high pressure (Sloan and Koh 2008). Because hydrates are solids, they can block oil and gas flowlines; flow assurance involves considerable effort and expense to ensure that this blockage does not happen. Also, hydrates concentrate hydrocarbon gases by a volumetric factor of 164 (at standard temperature/pressure), such that large deposits of natural hydrates are becoming factors in energy resources and climate concerns in marine and permafrost deposits.
A combination of applications, principally in flow assurance, energy, and, more recently, climate change, has driven hydrate engineering and science for 75 years. The number of published hydrate-related papers is an exponential function of time, extrapolating to more than two refereed publications per day in this decade. As Table 1 summarizes, triennial international hydrate conferences have been held since 1993; the most recent conference, in July 2008, presented more than 400 manuscripts.
The Role of Gas Processing in the Natural-Gas Value Chain
Authors: Hubbard Robert 
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.

Abstract
Production of natural gas is the first step in the value chain that takes gas from the reservoir to the customer (typically at a burner-tip). An integral and essential part of this value chain is the midstream sector. Midstream refers to the gathering, compression, and processing functions required between the wellhead and the transmission system.
Midstream assets and activities are found at any location where natural gas is produced, transported, or sold. For example, in North America the first gas-gathering and -processing facilities were installed circa 1910, primarily to extract casinghead gasoline from solution gas produced with crude oil. In Europe, the midstream sector developed in the 1960s with the discovery of large nonassociated-gas fields in the southern North Sea and in the Groningen field in The Netherlands. Industry development in the Middle East was spurred by the huge associated-gas-gathering and -processing projects initiated by Saudi Aramco in the late 1970s and early 1980s. Fig. 1 shows a schematic of the gas-gathering and -processing facilities in the total production system. This article discusses the gas-processing portion of the midstream sector, with the primary objective of providing technical professionals on the upstream side of the industry some insight into the midstream sector.

Gas Conditioning and Sales-Gas Specifications
One of the principal objectives of the gas-processing industry is to condition the gas for sale. Natural gas must meet several specifications before it can enter the transmission system. Historically, these specifications have been referred to as "sales-gas specifications," but in many areas they are really transportation specifications. This is because gas from many producers will be transported in "open-access" gas pipelines to the gas buyers along the pipe route. The sales agreement may be between the producer and the buyer, but there is no guarantee the buyer will actually receive the producer's molecules. In North America, for example, producers negotiate transportation agreements with pipelines and must meet the shipper's transportation specifications before the pipeline operator will accept the gas. These specifications are set out in the tariff the shipper files with the US Federal Energy Regulatory Commission. Table 1 shows some example sales/ transportation specifications in North America and Europe.
Challenges of Gas Well Completions: Recent SPDC Experience
Authors: Nnanna Erasmus , Ekeigwe Augustine , Alaka Collins , Owolabi Segun 
Published: June 2014

Abstract
Increase in both export and domestic gas demand has led to increase in the development of high rate gas wells by the Shell Petroleum Development Company of Nigeria (SPDC). Ability to deliver at expected potential and ensure integrity is a very critical factor to guarantee sustained gas supply and safeguard contractual obligations.
In the light of this, over the last five years, different operational challenges such as the inability to deploy sand screen across target intervals, parting of screens during deployment and casing deployment shallower than planned setting depth have been experienced.
This paper highlights some of the challenges encountered during the completion of these wells and the recovery strategies adopted that led to the successful implementation culminating in minimal loss in well potential and access to developed reserves.
Results of Gas Injection in the Cedar Lake Field
Authors: Leibrock R.M. , Hiltz R.G. , Huzarevich J.E. 
Published: June 2014

Abstract
The various factors considered in recommending the initiation of a gas injection project in the southern portion of the Cedar Lake Field are discussed. Performance history under gas injection operations is reviewed and these data are analyzed, utilizing both the material balance method and the fractional flow and frontal advance expressions.
Results of the analysis of the performance data indicate that the injected gas has contacted and affected at least 60 per cent of the reservoir and a substantial increase in ultimate recovery can reasonably be expected. By holding the reservoir pressure appreciably above the bubble point, the well productive capacities have been maintained substantially above the level predicted for primary operations.
The analysis of the Cedar Lake project suggests that in certain limestone reservoirs, at least, the probable success of gas injection cannot be predicted simply from observation of permeability distribution throughout the pay section, as indicated by core analysis data, on either one or a number of wells. Further, the performance of this particular project fails to indicate any basis for classifying carbonate reservoirs in general as being inherently unsuited to a dispersed type gas injection program, thus indicating that each reservoir should be considered on its own merits, regardless of the composition of the reservoir rock.

Introduction
Early in the life of the Cedar Lake Field, an extensive data gathering program was initiated to provide an accurate record of reservoir performance characteristics. From the study of these data it was apparent that there was a critical need for supplementing the natural reservoir energy in order to maintain well productivities and obtain the maximum ultimate oil recovery. Accordingly, detailed engineering studies were made of the various methods of secondary recovery which might be applicable. As a result of these investigations, the decision was made to initiate a gas injection program of sufficient intensity to maintain reservoir pressure at approximately 600 psia, or some 274 lb above the bubble point pressure of 326 psia.
Numerical Simulation of Wellbore Dynamics During Underbalanced Perforation
Authors: Bahrami H. , Siavoshi J. , Veisi M. Sheikh , Bahraie R. 
Published: June 2014

Abstract
The main objective of perforating is to connect the wellbore to the reservoir zone by creating tunnels through casing and damaged zone into the undamaged rock. The process of detonating perforation charges generally causes damage due to crushed rock material around the perforation tunnels.
There are different methods used to mitigate damage due to perforation, such as static and dynamic underbalanced perforation. In static underbalanced perforation, conventional high shot density perforating guns are run in underbalanced conditions in order to have clean-up after perforation. In dynamic underbalanced perforation, a specific gun design associated with gun puncher charges provides dynamic underbalanced conditions across the perforated interval immediately following charge detonation in order to efficiently clean up each single perforation tunnel from crashed rocks and debris.
Using deep penetrating charges followed by a dynamic underbalanced can improve well productivity since it mitigates the damage related to perforation. Dynamic underbalanced perforation removes the crushed rocks and debris from the tunnels using a sudden pressure drawdown across the perforated interval immediately after detonating the charges.
This study is intended to numerically simulate the dynamic underbalanced conditions after perforation in order to have a better understanding about the phenomenon during perforation process as well as perforation cleanup. The effect of wellbore fluid type on dynamic underbalanced behavior has been simulated to investigate efficiency of dynamic underbalanced in different wellbore conditions, and also three field examples are also shown to verify the simulation results.
Streamline Simulation with Compressibility and Spatial and Dynamic Variation in Oil Composition
Authors: Beraldo Valcir Tadeu 
Published: June 2014

Abstract
There are several oil fields offshore Brazil with horizontal oil density variations. API tracking, that is available in some commercial finite difference simulators, can deal with such cases by allowing definition of an initial oil gravity distribution and tracking variations of oil density, due to the movement of oil.
Streamline-based simulators can be much faster than conventional finite difference simulators when applied to large and heterogeneous models. However, this approach is most accurate and efficient when it is assumed that the rock and fluids are incompressible. In previous work (Beraldo et al, 2007), an incompressible formulation for streamline simulation with an API Tracking option using two components in the oleic phase was presented.
This paper presents a compressible formulation for streamlines that also considers API tracking. It extends the work of Cheng et al. (2006) and Osako and Datta-Gupta (2007) by consistently accounting for flux of mass and volume along streamlines. It was described how mass and volume can be mapped between the underlying grid and streamlines to minimize mass balance errors and how consideration of cumulative volume in a streamline can substitute for time-of-flight (Beraldo 2008).
The method was implemented in a three-dimensional two-phase streamline-based simulator. Tests based on a Brazilian oilfield model and on the SPE10th Comparative Case demonstrate that the implementation can reproduce the results of a conventional simulator, while being substantially faster for finely-resolved models, even when compressibility is significant.