bluuebunny/crossref_metadata_2025_split huggingface dataset:
An Experimental Investigation on Use of Nanoparticles as Fluid Loss Additives in a Surfactant - Polymer Based Drilling Fluids
Authors: Srivatsa Jayanth T. , Ziaja Malgorzata Barbara 
Published: March 2015

Abstract
As we approach an age of deeper discoveries in hostile environments, we need to either improve on existing drilling fluids or design new ones in order to meet the technological demands for success. The filtrate invasion is the most critical parameter that may cause a wellbore failure if not properly controlled. Also, the filtrate induced formation damage and problems with filter cake removal adversely affect the well productivity or injectivity.
The literature survey reveals the advantages of polymer, surfactant and Nanoparticles systems independently and also combination of two of these. A study is necessary to see the effect and advantages of combining all three systems together i.e. a Polymer-Surfactant-Nanoparticles system and to measure the rheological and fluid loss characteristics of the complex combined drilling fluid system. An attempt to study the same has been made in paper. Therefore, in this paper the authors present the results of testing the rheological properties and the API filtrate loss of a Bio-Polymer and Surfactant blend system with addition of Nanoparticles and compare the fluid loss reduction by using Nanoparticles as fluid loss additive with an industry standard polymer-based fluid loss additive
The objective of this research was to study the effectiveness of a Bio Polymer - Surfactant fluid blends, containing Nanoparticles as fluid loss additives in reducing the filtrate losses to the formation by forming a thin, non-erodible filter cake.
Laboratory experiments were carried out for the different combination of polymer and surfactant with varying concentrations to find the optimum of fluid performance. The laboratory measurements included measuring mud weight, pH, viscosity, gel strength, standard API filter test and High Temperature High Pressure (HTHP) test using Permeability Plugging Apparatus.
Presented results show that sized silica nanoparticles can be used instead of sized calcium carbonates which are a very effective inorganic bridging agent, however, difficult to maintain. The polymer - surfactant blend is better in rheological properties as well fluid loss properties than a Bio-Polymer based fluid or Surfactant based fluid. It captures the merits of both fluid systems. The nanoparticles play an important role in reducing the fluid loss of the individual fluid systems.
Also, the nanoparticles based Polymer-Surfactant blend is a good solution for solids free reservoir drill in fluids for horizontal shale drilling applications. The nanoparticles is most effective for shale drilling application as it can penetrate the pores of the shale and act as a bridging material and causing wellbore strengthening.
Searching for the Missing Link: The Regressive System Tract - Seismic Stratigraphic Evidence from the Southern Gulf of Thailand
Authors: Pigott John D. , Zhai Rui , Pigott Kulwadee , Tonianse Tatiya 
Published: March 2015

Abstract
High resolution seismic stratigraphic and geomorphic analysis of some 600 km2 of offshore 3D seismic data from the southern Gulf of Thailand reveal the preservation of a complete eustatic cycle on a Quaternary tropical coastal plain that is periodically affected by oscillating sea levels. While the dominantly aggradational interfluvial coastal plain records only the classic deltaic Parasequence Set signatures (PSS) of the Highstand Systems Tract (HST), Low stand Systems Tract (LST), and Transgressive Systems Tract (TST) stages capped by regionally pervasive ravinement surfaces, the erosionally incised intrafluvial rivers on the plain record an additional PSS, which is defined as the Regressive Systems Tract (RST). The RST is represented by downward stepping fluvial terraces in response to downward stepping base levels. Placing coastal river deposits within a sequence stratigraphic framework and the recognition of the RST afford significant insight into both the dynamic response of rivers to eustatic changes and to their petroleum system potential. The four complete PSS observed within the intrafluvial alluvial plain and their major characteristics are:1. HST: Highest base level where channels are widest, have the lowest gradients, and carry the finest sediment load. Such reservoirs would have poorest sand quality and seal potential.2. RST: Falling base level where channels tend to have lower width/thickness ratios and lower sinuoisities. Stages of erosional downcutting into the preceding HST deposits develop with the formation of terraces of lateral accretion units which can be seismically imaged as alternating oblique bands of amplitude polarity reversals in cross section and zebraic in plane section. Good reservoir sand quality and vertical but laterally disconnected geometries occur.3. LST: Lowest base level with the occurrence of maximum downcutting of principal channels and the development of serrated subordinate tributaries. Fluvial channels exhibit low sinuosities with potentially good reservoir continuity, sand quality, and charging potential.4. TST: Rising base level in which channels progressively widen and the subordinate tributary boundaries flood, yielding less favorable reservoirs but with potentially good source and seal potential.
Application of Distributed Temperature Measurements to Estimate Zonal Flow Rate and Pressure
Authors: Muradov Khafiz Mikhailovich , Davies David R. 
Published: March 2015

Abstract
Wells equipped with optic fiber Distributed Temperature Sensors (DTS) provide real-time downhole flow rate information offering an opportunity for effective production management in real-time. The downhole information can also be used to update the reservoir model, leading to a better description of the reservoir, an improved performance prediction and to a more effective, reservoir depletion strategy. Numerous publications describe smart well control and monitoring systems and improved production case histories.
Temperature measurements play important role in downhole monitoring in intelligent wells. DTS analysis is specifically important for wells with a number of production or injection intervals where the rate allocation is required for the effective reservoir performance and recovery monitoring. Distributed temperature data can be either analyzed using classical (production logging) methods of thermometry or calculated with recently developed models and software tools, the matched measured and calculated temperature profiles being used to estimate the wellbore flow rate distribution.
In this paper we will provide an overview of the currently applied distributed temperature monitoring and interpretation methods. Novel approaches for DTS data analysis measured during multi-rate well tests and for advanced completions with their complex flow paths will be presented. The approaches are mostly based on the robust, classical methods and can be extended to zonal flow rate as well as pressure calculation. Utility of the distributed data interpretation workflows will be demonstrated.
The proposed workflow can be used for zonal flow rate and pressure allocation in wells equipped with DTS. It extends the information capacity of DTS data towards more effective well and reservoir performance monitoring level.
Examples of 4D Studies from Kuwait
Authors: El-emam Adel Hassan , Zahran Wael Abdel-alim 
Published: March 2015

Introduction
The use of the Time Lapse, or 4D, seismic technology is well established in the marine offshore seismic environment, this technology is not so well established yet in the land seismic environment
The effectiveness of 4D seismic surveys for monitoring production-induced effects in the reservoir is determined by the magnitude of the change in seismic response and by the repeatability of the seismic experiments over the time periods.
KOC has recognized the significance and potential of 4D seismic as a powerful and cost effective tool for reservoir management. KOC also comprehends the need to test and evaluate all available, and the emerging, technologies to make 4D successful. In this paper we review several 4D examples, with emphasize on a repeatability study onshore conducted in North Kuwait and a 4D reservoir study performed in Minagish field; West Kuwait.

History of 4D seismic in Kuwait
Between 1996 and 1999, during the acquisition of the 2D and 3D seismic surveys across the State of Kuwait, KOC Exploration Group made the decision to evaluate the effectiveness of 4D seismic as a tool for reservoir production monitoring over some of its key producing fields.
Four pilot areas were selected over the Minagish, Raudhatain, Sabiriyah and Burgan fields (Figure 1). A small time lapse pilot seismic surveys varying in size from 9 Km² to 50 Km² were acquired and processed. The two pilots with the greatest potential were subsequently re-processed using the latest 4D analysis and processing techniques.
In 2004 KOC demonstrated its position at the leading edge of Time Lapse technology by carrying out the first seismic study in the Middle East using single sensor seismic over the 4D pilot area in the Minagish field.
The fine spatial sampling obtained by single sensor technology provides highly effective coherent noise attenuation, by attenuating such noise the signal to noise levels of Time Lapse data improved to the point where the subtle changes in acoustic impedance due to fluid changes in the carbonate Minagish Oolite reservoir could be more effectively detected.
Integration of Basin Modelling, Uncertainty Analysis, HC Charge Volume Assessment in Petroleum Exploration Risk Evaluation
Authors: Liu Jianchang , Katz Barry J. 
Published: March 2015

Abstract
Recent developments in hydrocarbon (HC) exploration have necessitated the strengthening and greater integration of geologic model building. Robust basin modeling requires a two-step procedure consisting of constructing reliable input frameworks that are consistent with available data and geologic interpretations and related geohistory processes and conducting basin simulation tests to explore and determine the confidence level of modeling results.
Integrating structural components such as faulting and salt movement is a key element and requires their restoration through time. These restorations impact our understanding of basin development, HC migration patterns, fetch areas, as well as the assessment of potential HC volumes.
The granularity or resolution of the stratigraphic input may also alter the modeled migration pattern, including the relative importance of lateral and vertical components and distance.
Key modeling input parameters include the source rock distribution through time and space. This input can be developed through the integration of geochemical data with stratigraphy, paleo-bathymetric framework, and other basin specific conditions (e.g., paleolatitude). As a result, a 3-D framework of organic richness and kerogen type can be developed.
The restorations and interpretations are imbedded within the basin modeling workflow and iteratively interact with the basin's burial history modeling. This iterative approach along with the numeric simulator accomplishes the integration and optimization of the input geologic model and directly yields more realistic modeling results consistent with the basin's specific geology.
Finally, in order to capture the full range of uncertainty in the petroleum system and to objectively evaluate the hydrocarbon potential and risks in the basin, a suite of simulations need to be performed using a probabilistic approach to determine the confidence level to be placed on the HC volume potential and risks in the analyzed basin.
Mini DST to Characterise Formation Deliverability in Unconventional Reservoirs
Authors: Kurtoglu B. , Kazemi H. , Boratko E.C. , Tucker J. , Daniels R. 
Published: March 2015

Abstract
Characterization of reservoir deliverability is fundamental for the economic development of any field. In the Bakken, a need exists for reliable pressure transient tests to provide effective formation permeability of the combined fracture-matrix porous formation. This effective permeability can then be compared to laboratory measured core permeability of the matrix rock samples. This comparison is the basis for planning early production options and subsequent decisions for EOR alternatives. In the Bakken this understanding is particularly important because of the influence of massive hydraulic fracture stimulation on reservoir performance.
Determining well deliverability potential by conventional drill stem tests (DST) or traditional wireline formation tests (WFT) in the past has resulted in mixed success in the Bakken. On the other hand, the mini-DST has definitely increased reliability and the success rate of pressure transient tests. The operation of mini-DST tool requires much less time than the classic DST, and multiple zone tests can be conducted to assess individual zone deliverability. The Mini-DST tool uses the conventional Wireline Formation Tester (WFT) configured with a dual-packer module and downhole pump. Tests are conducted by inflating the dual-packer module to isolate a 3-foot interval of the wellbore. Then, formation fluid is pumped out from the packer-isolated wellbore interval followed by a pressure buildup in the interval. Some simple overlay comparisons, as well as conventional pressure transient analysis, are used to interpret the drawdown and buildup pressure responses.
In this paper we present several field tests which were analyzed both by conventional pressure transient analysis and numerical simulation. The analyses have provided insight into a better understanding of the flow mechanism in the Bakken both during primary production and in forecasting various improved and enhanced oil recovery proposals. The experience can also serve as a basis for test design in similar low-permeability reservoirs.
Study of Progressive Flow Profile of Multiphase (Oil-Water-Gas) Flow for Downhole Monitoring Applications
Authors: Rawool Amitkumar , Pawar Bharat , Naik Harit 
Published: March 2015

Abstract
Computational fluid dynamics (CFD) has been actively used to make flow profile predictions in down hole oil and gas environments. The flow in oil wells inherently consists of oil, water, and gas phases. Flow profile predictions are complicated by parameters such as fluid properties, flow velocities, area, and well inclination. A proper understanding of flow behavior under various operating conditions is critical when designing down hole equipment and flowmetering applications.
This paper presents case studies involving the three-phase flow of oil-water-gas in a down hole tubular. Phase distribution is analyzed for different compositions by varying the individual phase volume fractions. Various flow regimes, such as stratified flow, homogeneous flow, and bubbly flow, are studied individually as well as in their transition from one regime to another. The transition criteria were also studied. Extensive efforts were focused on understanding random bubble distribution, bubble breakup, bubble-relative movement, distortion, and diffusion in fluid flow with respect to flow variables. Finite volume phase distribution for oil vs. water is obtained as a function of time and distance (coherence) for multiphase flow in production tubulars. The effect of geometry changes with the objective of flow homogenization is also studied to enable the locations and numbers of monitoring devices to be fixed. CFD results were found to be comparable to single-phase analytical solutions. The examples and references included in the paper demonstrate the accuracy of the study results.
The studies verify that an understanding of flow dynamics is essential to evaluate optimum configurations of the variables described. Advanced knowledge of flow characteristics enables engineers to deliver robust and maintenance-free sensing technology for use in a subterranean environment.
New Stimulation Technologies in a Major Gas Field in the Middle East
Authors: Al-Ghazal Mohammed , Al-Driweesh Saad , Al-Sagr Abdulaziz , Al-Ghurairi Fadel 
Published: March 2015

Abstract
In their natural state, most gas wells in the Middle East do not produce at their optimum level. This is mainly attributable to formation tightness or near-wellbore damage caused by drilling operations; however, a properly designed and executed stimulation program can enable more commercial gas production rates at higher flowing wellhead pressures (FWHPs). For this reason, and others, stimulation jobs (e.g., hydraulic fracturing and matrix acidizing) are common completion operations in the Middle East.
In recent years, stimulation technologies have witnessed major advances, as their use has been the main driver for production from tight reservoirs worldwide. This paper outlines eight new stimulation technologies that have been recently deployed in a major gas field in the Middle East. In addition, the paper looks at candidate selection, the main characteristics and benefits of the technologies, and post-treatment results.
Overall, the production results from the use of these technologies have been very positive and impressive, and the forecast is that their implementation will grow considerably over the coming years. The value of these new technologies will become even more significant as our industry accelerates the development of unconventional resources.
A New Method for OBM Decontamination in Downhole Fluid Analysis
Authors: Zuo Julian Y. , Creek Jefferson , Mullins Oliver C. , Chen Li , Zhang Dan , Jia Na 
Published: March 2015

Abstract
Downhole fluid analysis (DFA) has been used successfully to delineate reservoir vertical and lateral connectivity and properties of the produced fluids. The DFA tools can measure bulk fluid properties such as gas/oil ratio (GOR), light-end compositions (CO2, C1, C2, C3-C5 and C6+), oil-based mud (OBM) filtrate contamination level, color (optical density) that is linearly related to the heavy ends (asphaltenes and/or resins), live fluid density and viscosity, etc. in real time at downhole conditions.
Because of overbalance of drilling and formation pressures, and miscibility of OBM filtrate with formation hydrocarbons, the sampled hydrocarbon fluid is usually contaminated by OBM filtrate. This OBM filtrate contamination affects an accurate characterization of the reservoir fluid. On the other hand, DFA flowline temperature is slightly different than formation temperature. DFA flowline pressure, however, may be significantly different from formation pressure because the flowline pressure can be below the formation pressure when the DFA sensor is beside the probe/packer or above the formation pressure when it is on the output side of the pumpout within the Wireline Formation Tester (WFT). Therefore, decontamination of OBM filtrate on fluid properties and conversion of them from flowline to formation conditions are of great importance to interpret DFA measurements.
A new reliable method has been developed in real time for characterizing downhole reservoir fluids, decontaminating OBM filtrate on the DFA-measured fluid properties and converting the DFA data from the flowline to formation conditions. The method has been validated against laboratory measurements of different types of reservoir fluids and OBM filtrates with successful results. This methodology establishes a powerful approach for conducting decontamination of OBM filtrate on DFA measurements in real time at downhole conditions.
Case Study: Successful Application of Coiled Tubing Conveyed Inflatable Straddle Packer for Selective Reservoir Treatments in Deviated and Horizontal Wells of Rajasthan Field, India
Authors: Singh Alok Kumar , Kothiyal Manish Dutt , Kumar Prakash , Sharma Anurag , Mahajan Mahesh 
Published: March 2015

Abstract
Field X in Rajasthan, India has been developed with 22 Injectors wells &40 Producers wells. Most of the producers are completed with standalone screens of different types like conventional, ICD's and SSD types. Almost 60% of the producers are completed with ICD type screens. The open hole for screens section has been drilled with 10.2 ppg SBDIF (Synthetic based drilling fluid)which includes dolomite and barite as weighting agents. After running the screens, the screen section is displaced with 8.4 ppg low weight SBDIF(Synthetic based Drill-In Fluid) which has organophilic clay (Viscosifier) and emulsifier as the key components. Due to some operational delay in bringing the wells online, mud was left inside the screens for a few months. The deposition of mud filter cake and heavier hydrocarbon probably choked the ICD screen sensuing a number of ICD's non-contributing. Conventional stimulation techniquesdidn't help in achieving good results.
To effectively remove the suspected damage a coiled tubing based solution was implemented which involved the application of Inflatable Straddle Packer tool. It provides pinpoint accuracy for conventional, horizontal and multilateral stimulation treatments. Coiled Tubing Conveyed Re-Settables elective straddle packer elements allow multiple settings in one trip. Treatment Valve allows precise injection of treatment fluid & adjustable element spacing helps in straddling the long interval.
A case history of successful application of CT conveyed inflatable straddleapcker tool in field X in India is presented in this paper which enabled the correct placement of a series of stimulating chemicals targeting different damage mechanisms i.e. wax deposition, mud filter cake, inorganic scaling etc. Post stimulation production logs showed excellent improvement of conformance in zonal contributions.
The learning from this stimulation technique was also applied to the horizontal wells in field Y with very encouraging results.
Nanostructured Material Based Completion Tools Enhance Well Productivity
Authors: Xu Zhiyue , Richard Bennett M. , Solfronk Matthew D. 
Published: March 2015

Abstract
Making downhole completion tools interventionless is the ultimate level of integrated design of material and product that enhances well performance and saves operation time and cost. Two common approaches to interventionless tools are novel mechanical design and use of new engineered materials. New interventionless tool designs, though effective, are often limited to the small downhole geometry available. Use of high strength, disintegrable materials becomes a more attractive solution for downhole tools which require eventual removal after the tool completes its functions. This paper presents a new, groundbreaking, smart, disintegrable nanostructured composite (DNC) and its successful use for multistage fracturing tools to enhance shale gas/oil well productivity.
The disintegrable nanostructured composite (DNC) is manufactured through a powder metallurgy process by consolidating reactive metal powders that were coated with metallic and/or ceramic reinforcements. Material composition and microstructure were engineered at the micro- or nanoscale, to vary material strength and disintegration rate. The DNC is lighter than aluminum and stronger than some mild steels, but disintegrates when it is exposed to the appropriate fluid. More broadly, the DNC has the potential for radically changing the downhole tool functionality landscape by reducing product operational complexity and potentially the wholesale elimination of complete well trips by causing all, or a portion of, a tool to disintegrate in the well.