bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Decision Support Framework for the Technical and Economical Optimisation of the Supply Chain and Project Scheduling for Oil and Gas Projects Under Uncertainty – A Case Study Approach
Authors: Katterbauer Klemens 
Published: March 2016

Abstract
Supply chain optimization and optimizing the construction and field development schedule of oil and gas projects has become quintessential for energy companies in order to cope with changing economic situations, avoid cost overruns and delays in starting production. While the construction process and the individual tasks of it are determined in the planning stage and encounter only limited changes, the economic environment, the duration of tasks and other outside factors, such as the weather, are subject to strong uncertainty and hence this uncertainty needs to be taken into account in the planning and supply chain management process for oil and gas projects. We present a new framework for the integration of technical and economic uncertainties for optimizing the supply chain and the project schedules. Furthermore, we also integrate the option to establish regional distribution center facilities in order to route equipment and material through these facilities to the projects. The operations decision framework was then examined on a realistic test case in the northern Eurasian region where we performed a scenario based optimization in which certain transport links may break down due to either political, environmental or other reasons, affecting both the links as well as the duration of the project schedules. The results outline the importance of taking into account the uncertainty in order to create a sustainable value generating supply chain and project scheduling methodology. Furthermore, the results indicate that while robustness is critical, the establishment of a larger number of regional distribution center facilities is not necessitated in order to maintain robustness and minimize cost. Finally, given the target completion date, the framework delivers a schedule that with almost certainty leads even in various event scenarios to an in-time schedule.
Rheology and Temperature Dependency Study of Saraline-Based Super Lightweight Completion Fluid
Authors: Amir Zulhelmi , Jan Badrul Mohamed , Wahab Ahmad Khairi Abdul , Khalil Munawar , Tong Chong Wen 
Published: March 2016

AbstractOne of the effective alternatives to minimize this perforation-induced formation damage is by application of underbalanced perforation. Fluid systems with very low density could be used to perforate reservoirs in underbalanced pressure conditions that virtually eliminate or minimize fluid invasion and damage along perforation tunnels. To respond in the needs of such fluid, Saraline-based super lightweight completion fluid (SLWCF) was formulated from glass bubble, stabilizing and homogeneity agent. This paper focuses on a rheological and statistical evaluation of Saraline-based SLWCF and its effect on operating temperature. Eight rheological models, namely the Bingham plastic, Ostwald-de Waele, Herschel-Bulkley, Casson, Sisko, Robertson-Stiff, Heinz-Casson, and Mizrahi-Berk, were used to describe the rheological behavior of the fluid. Based on the results, rheology of the fluid was best represented by both the Sisko and the Mizrahi-Berk models. Furthermore, it is also found that the viscosity of Saraline-based SLWCF was more dependent to temperature changes at low shear rate. The Arrhenius activation energy for the fluid to flow was also found to be decreasing with shear rate and their relationship can be expressed with a power law equation.
Produced Water Management – The Challenges Faced
Authors: Ariaratnam G. D. , Roth N. J. 
Published: March 2016

Abstract
In this paper we will discuss the factors that influence the strategy for produced water treatment and disposal. Various aspects of the produced water treatment plant will have an impact on the water quality achieved, for example operational parameters such as interface levels, differential pressure ratios, flowrates, pressures, temperatures, etc. The required specification for either discharge or reinjection is a key factor in determining the process equipment and chemicals that are needed for the separation process. For injection, the water quality that needs to be achieved is often more stringent as there are limitations on solids loadings and particle sizes as well as oil concentrations.
In this paper we will review a detailed case study that was conducted offshore in the UK North Sea. This site was struggling to achieve the water quality needed for reinjection. The work conducted quantified the key areas that were causing the process problems and explored options such as optimising existing separation equipment as well as maximising chemical efficiency.
The case study will highlight how the overall process performance was improved once the oily water separation challenges faced were identified and understood. Improved water quality was achieved by enhancing the chemical dose rates for one chemical and eliminating the use of another chemical as well as optimising several operating parameters for different parts of the treatment process. The overall work led to reduced operation costs and reduced production time whilst ultimately achieving water quality within the required specification without affecting the export oil quality.
High-Resolution Seismic Stochastic Inversion as a Direct Input for Reservoir Modelling
Authors: Xin Chen , Wei Xiao-dong , Li Yan-jing , Cui Yi , Ma Yingzhe , Yan Xiao-huan , Xia Yaliang , Wang Guan , Wang Xiaotian 
Published: March 2016

Abstract
Three-dimensional (3D) reservoir models are best created with a combination of well logs and 3D seismic data. However, the effective integration of those results in the reservoir modeling was not easy due to limited seismic resolution. With the increasing quality of seismic data and widely application of new methods, High-resolution seismic stochastic inversion volume was used as a direct input to reduce the uncertainty of the reservoir model in this paper.
Through the past years study, workflows were developed which use the high resolution seismic stochastic inversion as a direct input for reservoir modeling. The workflows mainly include three steps. The first step is target processing. Wavelet transform was applied to achieve noise elimination and resolution improvement. Base on the High-resolution seismic data, the second step is seismic stochastic inversion. After the process of time-depth conversion, the high resolution 3D data from seismic stochastic seismic inversion and well logs data were used to reservoir modeling as a direct input.
Experiment results show that noise elimination and resolution improvement achieved by using wavelet transform brings desirable convenience, high efficiency and good fidelity. The seismic response of sand reservoir in the high resolution seismic section becomes clearer than the seismic data before target processing, and matched with the well log interpretation. As the seismic stochastic inversion process is controlled not only by the acoustic impedance features, variographic model, and histogram, but also by high-resolution seismic data, the possible number of solutions is reduced, thus decreasing the nonuniqueness of the solution. The seismic stochastic inversion results were multiple 3D volumes with the same horizontal resolution of the seismic and with the vertical resolution, which is matched with the well data. The reservoir model base on the high-resolution 3D data from seismic stochastic inversion and well logs data will reduce the uncertainty greatly, especially in the area Where reservoir exhibits strong heterogeneity. A postmortem is presented showing a successful well that were better explained by this model result based on data existing before the well were drilled.
With the increasing quality of seismic data, and the progress of target processing, seismic stochastic inversion and reservoir modeling technology, the high-resolution seismic data will play more and more important role in reservoir modeling. High-resolution seismic stochastic inversion as a direct input for reservoir modeling will reduce the uncertainty of model greatly.
Study of the Effects of Wettability Changes on Three-Phase Flow in Porous Media Through Pore Network Modelling
Authors: Raman Aarthy , van Dijke Marinus I. J. 
Published: March 2016

Abstract
The increased reliance on CO2 sequestration and Enhanced Oil Recovery techniques such as tertiary gas injection or WAG for oil field development has necessitated an in depth analysis of three-phase flow in porous media for reservoir modelling and production enhancement techniques. Prediction of three-phase flow phenomena requires a sound understanding of the fundamental flow physics in water-wet, intermediate and oil-wet rocks in order to derive physically robust flow functions, namely relative permeability and capillary pressure curves.
A new pore-network model for rocks with arbitrary wettability employing the thermodynamic oil formation and collapse criteria was developed and successfully validated by Al Dhahli et al. in January 2013. This model has been used in the current study to assess the influence of network extraction methodologies, wettability alteration after ageing and capillary effects on multiphase flow characteristics at pore level. Also, the study aims to understand the effects of capillary height functions on flow phenomena. These analogies are successfully illustrated for the Berea sandstone network models.
The flow functions for pore-network analyses were subsequently imported to a reservoir model so as to carry out pore to reservoir scale integration. Flow function normalization and de-normalization were performed with respect to the flowing fluid saturations. This aided in better curve interpolations and fewer curve smoothening. Consequently, curve interpolations based on flowing saturations are suggested for three-phase pore- to reservoir scale integrations in future analyses.
Pore network extraction and flow modelling has contributed to a paradigm shift in today's reservoir modelling approach. However, these applications are presently being limited to research level only and pore scale modelling is still in a relatively nascent stage. Near reservoir conditions such as intermediate wettability, variable flow functions and reservoir heterogeneity form a part of future work in this subject. Further study in this field can delineate dynamic properties of the reservoir, bringing the industry one step closer to effectively recovering immobile/trapped fluid from brown field reservoirs.
Zonal Water Injection for Offshore Highly-Deviated Wells
Authors: Sun Fuchao , Pei Xiaohan , Liu He , Zhang Yusheng , Song Xianmin , Hu Huili 
Published: March 2016

Abstract
Water injection is an effective way for maintenance of reservoir pressure, realization of high and stable oil production and improvement of oilfield development efficiency. Actually, it is a major way for oilfield development in China. Artificial island oilfields are often developed through highly-deviated wells. Existing water injection technologies feature a low pulling and running success ratio of downhole nozzles and pose difficulties in flowrate testing and adjustment, which can hardly meet the needs of zonal testing and adjustment of highly-deviated wells in offshore and artificial island oilfields. This paper proposes a concentric zonal water injection technology for highly-deviated wells. The technology adopts a concentric testing and adjustment scheme, wherein testing instruments and downhole regulators adopt concentric connection with a high connection success ratio for highly-deviated wells. Downhole regulator adopt a bridge channel design that can effectively eliminate the influence of interlayer interference and enhance the efficiency of testing and adjustment. Zonal flowrate is adjusted by adopting an eccentric valve design featuring small loss under fully closing state, small adjustment torque and more easy to adjust. Collected testing and non-collected testing are compatible to meet the requirements of low flowrate. Online packer seal test by cable is realized, ball sealing can be monitored, and all seal checking operations can be completed at one time. In order to achieve long-term continuous monitoring for zonal after-nozzle pressure, an equipped zonal pressure monitor is developed for acquiring long-term continuous data during water injection used for reservoir analysis. During testing and adjustment, online direct reading of multiple parameters (such as zonal flow, pressure and temperature) of any layer can be achieved together with the automatic testing and adjustment without pulling and running operation, which dramatically improves the efficiency of testing and flowrate adjustment. So far, field tests have been made for 14 wells with a maximum hole deviation angle of 59.4°. The flow testing error is less than 5%, and the time for packer seal checking, zonal testing and flowrate adjustment is less than 1 day. Comparing with existing technologies, this technology is of the characteristics of high efficiency of testing and adjustment, high accuracy, low cost, etc.
The Benefits of Detailed Global Analysis Modelling for the Installation of Flexibles, Umbilicals, and Rigid Pipelines
Authors: Jones Chris 
Published: March 2016

Abstract
Global analysis is required when installing flexibles, umbilicals and rigid lines in order to plan the operation and establish safe working environmental limits. Recent advances in modelling software and computing power mean that it is now feasible to model these operations in significantly more detail than has been previously considered. This paper provides an overview of the level of detail which can now be achieved, highlighting various operations which can be modelled and demonstrating how this can reduce risks as well as optimising operability during installation.
The paper focuses on the following areas: modelling techniques, modelling of offshore deck handling operations, and modelling the installation of a Pipeline End Termination (PLET). These case studies are used to highlight the benefits of detailed modelling in reducing risks for the actual operation offshore, in particular by studying the dynamic response as the equipment is installed, and how this relates to the accurate definition of a safe sea state limit. In the past, due to the high level of complexity, these operations have been engineered through the use of standardised calculations or through simplification of the modelling. Comparisons between the simplified and detailed analysis are made, highlighting the differences and the increased accuracy of results which may be obtained, showing areas where offshore installation may be executed more safely. Models are also be compared against the reality of the offshore installation to confirm the validity of the techniques described.
This provides an overview of the level of detail which can now be achieved with the following benefits:
Capturing critical motions which may have been previously missed due to over-simplification Modelling new stages of the operation which could not previously be covered
This will ultimately help to reduce risks as well as optimise operability during installation.
Laboratory Investigation on CO2 Foam Flooding for Mature Fields in Western Australia
Authors: Xu X. , Saeedi A. , Zhang Y. , Liu K. 
Published: March 2016

Abstract
Quantities of mature oil fields in the North West (NW) Shelf of Western Australia are characterized by high water cut and poor productivity, which makes them potential candidate for Enhanced Oil Recovery (EOR). In recent years, CO2 foam flooding has been widely recognized as a promising EOR method in terms of its outstanding ability to increase swept volume as well as improving the displacement efficiency.
In this paper we present the experimental investigation on the feasibility of applying CO2 foam flooding in mature oil fields in Western Australia. A procedure was firstly developed to screen ideal foaming agents at reservoir condition; furthermore, core flooding was performed to optimize operation parameters such as injection mode and volume ratio of aqueous phase to CO2.
The results demonstrate: 1) among a number of commonly used surfactants, AES exhibited the highest foambility and stability; 2) by adding 1.2% additive triethanolamine and 1500ppm polymer (AVS) into 0.5% AES solution, the stability of CO2 foam would be improved significantly without affecting the foamability considerably; 3) the foam stability increased with foam apparent viscosity; 4) the ultimate recovery of direct injection of foam was 7.72% and 4.09% higher than that of co-injection of solution and gas and surfactant-alternating-gas respectively; 5) under optimal flow rate and volume ratio of aqueous phase to gas phase, the oil recovery could go up to 30.05% after the water flooding.
Through systematic and thorough research, CO2 foam flooding has been shown to be a viable and effective EOR method assisting in maintaining the production in mature oil fields in the NW Shelf of Western Australia.
Using Multilaterals to Extend Well Life and Increase Reserves: Case History of an Offshore Thailand Project
Authors: Hogg C. , Cham S. , Hicks C. L. 
Published: March 2016

Abstract
This paper will detail a recent four-well TAML Level 4 multilateral (ML) installation in a field located offshore Thailand. The drivers that led the operator to seek out a first time multilateral solution for this field development will be covered, along with the variables considered in selecting the specific multilateral system that was ultimately chosen. Both the difficulties encountered and the successes achieved during the multilateral planning, installation and perforating processes will be covered.
Although ultimately successful in all four wells, the multilateral construction process was not without challenges. The shallow depths of the multilateral junctions and the resulting weak formations resulted in a need for maximum mechanical support at the junction. At the same time, the multilateral needed to use a minimum of specialized equipment and processes to meet the timing urgency resulting from the existing rig availability deadline. This short timing made equipment and personnel sourcing a vital factor in the eventual success of the project. The importation of the perforating charges that are used in this ML system was especially challenging and must be taken into greater consideration when planning future installations.
At the end of the project, the success of the installations was due in large part to the simplicity and reliability of the ML systems used, but another key factor in the success was the necessary and careful coordination of planning and activities between the operator and the service company providers involved in the multilateral construction process. The historical perception in the petroleum industry has often assumed that multilaterals require extensive lead times and that operating companies without previous multilateral experience face a steep learning curve to achieve successful results. The success of this project, however, demonstrates that today's multilaterals can be reliable and simple enough to consider even when time requirements are tight and in areas where multilaterals are considered a "newer" technology.
An EOS-Based Dynamic Modelling for Depressurisation of Pressure Vessels Containing Hydrocarbons
Authors: Jin Ryu Si , Ko Yoonae , Lim Youngsub 
Published: March 2016

Abstract
Managing overpressure of a pressure vessel is critical to the safety of a hydrocarbon producing facility. As a result of rapid depressurisation called blowdown, temperature of the pressure vessel wall can be severely decreased. For these reasons, dynamic behavior of properties (e.g., temperature in pressure vessels) during depressurisation has to be analyzed for material selection and design process. In this work, a dynamic model for depressurisation was developed to simulate the low temperature phenomena inside a pressure vessel under depressurzation. Thermodynamic and transport property calculation theories were used to describe hydrocarbon systems. Heat tranfers between internal fluid and inner wall surface and between surroundings and outer vessel wall surfaces were considered. Temperature of each vessel wall surface was calculated using transient conduction temperature profile. The result showed good fitting to reported experimental data.
Novel Methodology to Estimate Reservoir Pressure and Productivity Index in Unconventional and Conventional Reservoirs Using Production Data
Authors: Poe Bobby , Varma Gottumukkala 
Published: March 2016

AbstractEvaluation of the initial reservoir pore pressure, the current average prevailing reservoir pressure, and the deliverability of a well commonly results in the need for one or more pressure or rate-transient tests of a well's performance to be conducted in order to properly characterize the properties of the reservoir and the well completion efficiency. Conventional pressure build up or multi-rate drawdown tests have commonly been used for this purpose. These types of transient tests can last for days or even months in low-permeability unconventional reservoirs, resulting in prohibitive production deferments and operational expenditure. The reservoir pressure and the well deliverability are key indices that are used to properly characterize the reservoir properties and the expected ultimate recovery of a well.This paper presents the development and application of an elegant production performance analysis technique that can be used to accurately determine the initial and/or average prevailing reservoir pressure of both conventional and unconventional reservoirs (for any permeability level), for wells of any type, time level, inner and outer boundary condition and flow regime, using only transient well production data (flow rates and bottom hole flowing pressures as a function of time). With the improvements in accuracy that can now be achieved in determining the average reservoir pressure, reliable and accurate transient Productivity Index values can be obtained for producing wells.In addition to the improvement in determining the initial/average reservoir pressure, the newly developed production analysis procedure also provides an excellent means of Quality Control for the validity and consistency in the reported well flow rates as a function of the system drawdown. Examples are presented in this paper in which a variety of different flow rate measurement or estimation techniques have been utilized. These include a state-of-the-art advanced and extremely accurate surface multiphase flow rate metering system, flow rates computed from downhole flow control valve measurements, as well as an example in which well flow rates have been estimated using measurements obtained for monitoring the performance of an electrical submersible pump.The acquisition of extremely accurate, high-frequency production performance data greatly enhances the evaluation of the reservoir pressure obtained with the analysis technique presented in this paper. Temporal measurements of the sandface flowing pressures and flow rates, obtained for a time scale on the order of minutes or hours is often adequate for accurately determining the initial or current average reservoir pressure. However, the use of high-frequency production data obtained with permanent downhole gauges and surface (or downhole) continuous flow rate metering systems offer even greater precision in evaluating the reservoir pressure with this analysis.