bluuebunny/crossref_metadata_2025_split huggingface dataset:
Integration of a Risk-Management Tool and an Analytical Simulator for Assisted Decision Making in IOR
Authors: Alvarado V. , Reich E. -M. , Yi Y. , Potsch K. 
Published: December 2007

Abstract
Risk management has become an integral part of the decision-making workflow in the oil and gas upstream business. As many oil fields reach a mature state, the need for rejuvenation and decline mitigation of assets set ground for Improved-Oil Recovery (IOR) opportunities. However, the associated decision-making process requires incorporating screening, reservoir simulation and financial evaluation, demanding complex multidisciplinary team efforts. It is important that any stage of the analysis, technical, strategic and economically sound decisions should be made.
On one hand, IOR screening, whether based on technical grounds or ‘gut feeling’ experience, or better yet on both criteria, leaves a number of possible IOR processes available for evaluation through simulation. Analytical simulation and applicability screening tools are often favored on early stages. However, their crude application could mislead the decision process if results are not carefully interpreted and combined with reservoir engineering expertise and additional evaluation criteria.
We propose to combine IOR screening strategies with spatial reservoir information to help to create appropriate sector models as starting point for more detailed evaluations. For this purpose, we couple an analytical simulator/IOR screening tool with a software tool that aids framing the IOR decision-making problem effectively, in the form of influence diagrams. From these diagrams, it is possible to create Tornado Diagrams, Decision Trees and Monte Carlo profiles that assist Reservoir Engineers with the task of properly and rationally framing the decision process, for example with regard to economic risk assessment and NPV analysis associated with IOR.
The coupling between both software solutions is proposed in a way that avoids the inflexible monolithic constructions. We illustrate advantages of the proposed approach through a speedy analysis of a publicly available case.
New Work Processes and Operation Forms: Efficient Data Utilisation and Online Collaboration
Authors: Millette P. 
Published: December 2007

Abstract
Although producing oil is a complex activity, the support of the total operation of any producing asset is hampered by several factors – remote locations, limited data access, low bandwidth data connections, distributed specialists and fragmented support teams. At the same time pressures of less personnel in-situ at the production and support centres is increasingly evident.
Challenges also exist of trying to ensure the optimisation of Production and operate with zero accidents, safety compliance, additionally in a ever-changing world we face increasing environmental monitoring and compliance regulations
Increasingly industry is turning to the people factors to try and assist the Oil & Gas Industry achieve the above objectives. Industry shows that people factors account for 35%-45% of abnormal situations in the process industry however the team resolving these situations are effectively individuals working on a common problem, rather than a team working together. Predominantly, this is because the team cannot see the same thing or look at issues together in real-time.
Building Human Capital to Meet the Demands in Well Intervention
Authors: Allcorn M. , Zemlak W. M. , Van Der Tuin R. G. , Stephens R. K. 
Published: December 2007

Abstract
The pace of activity, maturing profiles, incoming workforce expectations, and increasingly focused requirements on the industry’s well intervention needs, is demanding a new approach to building human capital. Today’s challenge is to build the required expertise in a fraction of the time previously available. This paper will provide an overview of current and future skill requirements to determine the most effective way to develop those skills, and a review of on-going programs to develop the required skill levels. Additionally, a review will be completed on the current learning tools as well as the integration of those tools in a comprehensive and accelerated development program.
Injection Tests as a Reliable Alternative to Conventional Well Testing: A Real Field Experience
Authors: Beretta E. , Tiani A. , Presti G. Lo , Verga F. 
Published: December 2007

Abstract
Environmental constraints and high costs, especially offshore, are making conventional well testing less and less feasible and accepted by the public Administration.
New options were thoroughly evaluated to find a viable alternative to standard production tests for characterizing the well productivity without surface production. An accurate investigation demonstrated that injection tests could provide all the information needed to calculate the well productivity at reasonably low costs and with a good degree of reliability.
Based on the results of laboratory and field pilot tests it was proved that injectivity tests could be successfully applied in a real sour oil field. Laboratory tests proved that brine could be a suitable injection fluid because there were no compatibility problems with the oil and the reservoir rock. It was verified that the interpretation of the pressure transients should be referred to the fall-off period rather than to the injection phase. The formation permeability thickness product (kh) could be correctly identified from the pressure derivative analysis only if multiphase-flow was assumed. The total skin value could also be obtained from the test interpretation.
The total skin comprises two components, a mechanical component due to permeability damage, and a bi-phase component due to fluid interaction in the reservoir. The biphase skin could only be evaluated with numerical well testing, provided that the fluid relative permeability curves were available. It was also demonstrated that the bi-phase component mainly depends on the injection rate, but is independent from the formation permeability.
Then, the well-known transient equation was applied to determine the well productivity index (PI) based on the kh and the mechanical skin. PI values calculated from injection tests compared satisfactorily with PI values measured from 6 DST tests performed on appraisal wells.
Novel Fluid Design Can Eliminate OBM-Cuttings Waste
Authors: Young S. , Rabke S. 
Published: December 2007

Abstract
With an ever increasing pressure on drilling performance and economics, the use of invert emulsion fluids has continued to be a necessity. Increased environmental responsibility has brought with it an increase in the cost and liability associated with responsible disposal of contaminated drill cuttings. In environmentally sensitive areas, it is unlikely that any discharges of contaminated cuttings will be permitted. Subsurface injection cannot be used as a solution in all cases, so other treatment methods must be found to minimize future environmental liability.
Developing invert emulsion drilling fluids designed to meet the demands of high-performance drilling and have chemical characteristics that can be used to optimize contaminated cuttings treatment has been key in minimizing environmental impact. Developing efficient treatment techniques tailored to the local environment has been equally important. The environmental responsibility picture has been completed by combining the chemistry and treatments to produce an end product that can be beneficially re-used in the local environment.
The authors will discuss the design changes in drilling fluid chemistry and show the field performance of these fluids. The associated treatment techniques that can be applied will also be reviewed, along with the local environmental climate required to ensure successful application of such treatments. The authors also will review the potential for beneficial reuse of contaminated cuttings in this context and show field trial results.
Facies Connectivity Modelling: Analysis and Field Study
Authors: Nurafza P. R. , King P. R. , Masihi M. 
Published: December 2007

Abstract
A statistical approach is proposed and validated against a realistic field dataset to model connectivity of low to intermediate net-to-gross reservoirs. An object based technique is used to model the spatial distribution of aligned isotropic and anisotropic bodies. The connectivity of the model is estimated using percolation theory. First account is made to evaluate the effect of the aspect ratio of the facies. The outcome is two universal curves for the connectivity and its associated uncertainty which can be used to estimate the connectivity of all sorts of body sizes and aspect ratios very quickly.
The approach is then reviewed for variable body sizes as well as a system with oriented bodies. An effective size based on the square root of the average area of bodies can be used to represent the distribution of body sizes. For systems with oriented bodies, a new aspect ratio is defined and the reduced percolation thresholds of the system are determined. The results show that with above changes the universal curves are still applicable for both orientated and variable size systems.
Finally, a conventional facies modelling of a carbonate layered reservoir is used to be compared with the results of the proposed method. The comparisons were in good agreement. It is found that the new method gave reliable and broad estimate of connectivity of the system in comparison with exact and uncertain results from modelling of real data, while the first one is so fast, the latter is so costly and time consuming. This framework can be further extended to evaluate recovery factor and sweep efficiency of a reservoir. The technique can also be used for preliminary evaluation of a reservoir as a quick method which offers fast estimates of important parameters of a reservoir based on its simple basic data.
Magnetic Resonance While Drilling—A Quantum Leap in Everyday Petrophysics
Authors: Bittner R. , Komarek F. , Thern H. F. , Kruspe T. , Kirkwood A. , Chemali R. 
Published: December 2007

Abstract
Magnetic resonance (MR) logging was originally intended for measuring fluid filled porosity, and for differentiating between producible and non producible fluids. Early tools however came with special operational requirements. Wireline logs were slow and sensitive to wash-outs; early logging while drilling (LWD) measurements did not tolerate tool vibrations. Both required a good deal of preplanning to accommodate limited capability hardware. The paper shows how problems of the past could be solved by the innovative technology of Magnetic Resonance Logging While Drilling (MR-LWD).
By returning to basics a new LWD magnetic resonance tool tolerant to vibration and easy to apply could be designed. The novel device acquires valuable data which can be used as well for formation evaluation as for geo-steering under normal drilling conditions and with standard operating practices. This was made possible by a short inter-echo spacing, by a special stabilization, and by a low magnetic field gradient. The new sensor operates with a minimum of preplanning and requires little to no interference with the drilling process.
We present an application of the new system in a European onshore well. In the case described we show how reliable deliverables such as porosity and pore-size distribution can be determined from MR-LWD. Formation boundaries and fluid contact can easily be determined. The clear logs and the intuitive presentation of data makes MR while drilling ready for everyday petrophysics.
New Nitrate-Based Treatments—A Novel Approach To Control Hydrogen Sulfide in Reservoir and to Increase Oil Recovery
Authors: Anchliya A. 
Published: December 2007

Abstract
Biogenic formation of hydrogen sulfide has, and will, occur in most oil and gas reservoirs - particularly those flooded with sea water. Hydrogen sulfide causes high costs and serious operational problems, including reservoir souring, sulfide corrosion, iron sulfide plugging, reduced product value, and health and environmental hazards. Historically, the sulfide problem has been treated with toxic biocides, which have proven to be costly and mostly ineffective. The petroleum industry is now implementing a nitrate-based microbial treatment technology for both the prevention and removal of sulfide from reservoirs, produced water, surface facilities, pipelines and gas storage reservoirs, as well as increasing oil recovery. This innovative reservoir treatment technology recognizes that detrimental sulfate reducing bacteria (SRB), which produce sulfide, can be replaced by a naturally occurring suite of beneficial microorganisms enhanced by the introduction of an inorganic nitrate-based formulation. This designed manipulation of the reservoir ecology has been termed Bio-competitive Exclusion (BCX) technology. The Bio-Competitive Exclusion (BCX) biological process has also demonstrated significant application in the field of tertiary oil recovery. This is possible through the use of nitrate-based formulae as alternate electron acceptors and microbial nutrient. This nitrate based formulation is environment friendly and complement the naturally occurring volatile fatty acids (VFA) in the reservoir, selectively stimulating and increasing the targeted Nitrate-Reducing Bacteria (NRB).
This paper discusses novel action and advantages of BCX Technology for effective sulfide suppression when compared to previous biocide treatments. It also brings into light the two main approaches to solving the sulfide problem: proactive and reactive. Several examples of the BCX technology to treat sulfide problems are illustrated These results are reinforced by reports that both proactive and reactive nitrate treatment projects are now operational at several North Sea platforms, Such reported successes have resulted in the nitrate technology being applied to other North Sea fields including Norne, Statfjord, Valhall. The BCX technology offers a cost effective technique of sulfide removal and increased oil recovery.
Identifying and Correcting for High-Resistivity Cement Effects for Cased-Hole Resistivity-Log Analysis
Authors: May D. H. , Jacobsen S. , Rushing J. , Reynolds B. , Swager L. 
Published: December 2007

Abstract
The advent of a viable formation resistivity measurement through-casing has allowed for an order of magnitude increase in the confidence of through-casing formation evaluation.
The existing through-casing resistivity measurement is a laterolog type measurement. This means that the resistivity of the casing, cement and formation are added in series, or cumulatively. Most generic cements have a resistivity that is less than 5 ohm-m, so the effects of the cement resistivity are minimal.
In the early time period of the tool introduction, most of the wells logged were cemented with traditional class H cement systems. In more recent years, more exotic cement recipes have been used, resulting in cement resistivity values that are apparently higher than the norm.
We have found that wells cemented with lightweight cements, appear to have downhole cement resistivity values that range from the normal cement resistivity value of around 2.5 ohm-m to several hundred ohm-m. If high cement resistivity is not taken into account, the through-casing resistivity measurement will not be indicative of the formation resistivity.
This paper will detail methods to combine cement integrity measurements, resistivity modeling, and the through-casing resistivity measurement to identify high cement resistivities.
Once identified, this paper will also detail how to correct the through-casing resistivity measurement for the effects of high-resistivity cement. The resulting data can be used with the same confidence as that obtained in wells cemented with the more traditional cement recipes.
Effects of Residual Oil on Reinjection of Produced Water
Authors: Vaz A. S. L. , Bedrikovetsky P. , Furtado C. , Siqueira A. G. , de Souza A. L. S. 
Published: December 2007

Abstract
Injection of water with solid and oily particles happens during waterflooding using seawater, produced water and other waters of poor quality. The injected particles are captured by porous rock causing decrease of permeability, cake formation and consequent injectivity decline. Maintenance of the injection rate results in increase of pressure gradient near to well.
We consider effects of mobilization of residual oil in well vicinity due to increase of pressure gradient and, consequently, the increase of capillary number. The mobilized oil ganglia perform snap-off and release oil drops that move together with the injected particles; they are captured by porous rock causing additional formation damage.
In the current work a simplified analytical model that covers effects of oil drops generation and additional permeability reduction is developed. The model includes analytical expressions for deposition profiles, breakthrough curves and permeability decline. It was used for planning and design of laboratory test on injection of oily water into residual-oil-containing core.
The sensitivity study was performed with regards to flow velocity, injected concentration and formation damage parameters. The main result is an additional formation damage induced by particles released by residual oil.
New Developments in Sourceless Logging-While-Drilling Formation Evaluation: A Case Study From Southern Italy
Authors: Mirto E. , Weller G. , el-Halawani T. , Grau J. , Berheide M. , Allioli F. , Evans M. , Berto R. , Borghi M. , Firinu M. , Giorgioni M. 
Published: December 2007

Abstract
Radioactive chemical logging sources have been used in the E&P industry for many years to help operators obtain valuable information about their reservoirs. Until recently, much of the information obtained using these sources could not be obtained with any other method. While the potential risks involved with the use of such sources have always been known, more awareness in the industry has led to increased efforts towards the reduction or even elimination of the use of chemical sources where possible.
A new Logging-While-Drilling (LWD) tool has been developed, using innovative technology to provide a complete suite of formation evaluation measurements without having to use a chemical radioactive logging source. The use of a non-chemical radioactive source significantly reduces the environmental and operational risks normally involved with traditional LWD tools.
The data delivered by this service include not only the traditional measurements such as gamma ray, resistivity, density, and neutron porosity, but also measurements not previously available in LWD such as formation capture cross section (sigma) and elemental analysis from neutron capture spectroscopy used to compute formation mineralogy. An entirely new LWD measurement has also been introduced with the tool, making it possible for the first time to determine formation density without the use of a chemical logging source.
A case study is presented of a well situated in a field in southern Italy, inside an environmentally sensitive national park. Because of the location of the well, it has not been possible to use radioactive logging sources for formation evaluation. As a result, fully evaluating the reserves has been an ongoing challenge for the operator. In addition, because of the move towards high angle and horizontal wells, wireline formation evaluation acquisition has been, at times, replaced by LWD.
The new LWD tool allowed the operator to not only improve efficiency, but also brought with it the possibility of more completely evaluating the diagenetically complex tight carbonate reservoir through the use of the new measurements. The favourable environmental conditions (low temperature and low mud salinity) made it possible to obtain additional spectral data, which was used to correct the neutron porosity measurement for lithology effects, despite the presence of dolomite.
The results of the formation evaluation studies are presented, together with an analysis of the impact on operational efficiency and environmental and operational safety as a result of not having to use a chemical logging source.
Development and Deployment of Improved Performance "Green" Combined Scale/Corrosion Inhibitor for Subsea and Topside Application, North Sea Basin
Authors: Feasey N. D. , Jordan M. M. , Budge M. , Robb M. 
Published: December 2007

Abstract
Effective scale and corrosion control in production of hydrocarbon deposits is in many fields essential to the economic and safe production of these fluids. This paper presents field results and lessons learned from a North Sea field where a combined scale and corrosion inhibitor has been applied using a single formulation to control both the deposition of scale and associated corrosion. The use of a single product has facilitated a reduction in the number of umbilical lines to be used to provide flow assurance on the subsea flow lines and topside process of this facility. As part of the drive to reduce the environmental impact of production chemicals an improved performance formulation was developed. This formulation was required to contain no material on the current North Sea production chemical substitution list.
The laboratory methods used to select the product along with measurement methods used in the field are also discussed. The impact of current environmental legislation on raw material selection will also be outlined. The validation of the laboratory selection methods in the field required the development of a monitoring program to establish base line control and to assess the degree of protection from scale deposition and corrosion across the process.
The changing physical conditions within the flow lines and across the topside process will be described, as well as the changes in brine chemistry within the field, as injection water breakthrough occurred. This is vital for understanding how flow assurance was maintained and how treatment rates and products could be optimised.
This paper will outline in detail the particular issues associated with chemical injection to a subsea facility, many of which are currently being developed in the Gulf of Mexico and West Africa.