bluuebunny/crossref_metadata_2025_split huggingface dataset:
Investigation of Wettability Alteration and Oil-Recovery Improvement by Low-Salinity Water in Sandstone Rock
Authors: Nasralla Ramez A. , Bataweel Mohammed A. , Nasr-El-Din Hisham A. 
Published: June 2014

Summary
Optimization of any oil-recovery process is based on understanding of the recovery mechanisms, whereas the underlying mechanisms of improving oil recovery by low-salinity-water injection are still debated. Wettability alteration is one of the mechanisms suggested to be the primary mechanism of low-salinity water. Therefore, wettability alteration by low-salinity water in sandstone reservoirs is examined by using the contact-angle technique. The effect of changing ionic strength on the electrokinetic charges is investigated by use of the zeta-potential technique to explain the causes of wettability alteration by low-salinity water. Moreover, coreflood experiments were performed in order to correlate between the wettability alteration and oil-recovery improvement caused by low-salinity water. Mica sheets were used for the contact-angle measurements to represent sandstone rock. The effect of water salinity on wettability was studied by using synthetic water over a wide range of salinities (from 0 to 174 000 mg/L), with two different crude oils at different conditions of pressure and temperature. Zeta-potential tests were conducted to measure the electrokinetic charges for combinations of each of the two crude oils or Berea sandstone and different brines. Berea sandstone cores were used for waterflooding experiments by injecting the same brines tested in the wettability measurements. Low-salinity water showed lower contact angles compared with high-salinity water for the two types of crude oil, which demonstrates the ability of low-salinity water to alter the rock wettability to more water-wet. In addition, low-salinity water made the surface charges at rock/brine and oil/brine interfaces strongly negative. As a result, the repulsive forces between rock and oil surfaces increase, which leads to expansion of the double-layer and, consequently, wettability alteration and oil-recovery improvement as confirmed by coreflood experiments.
A Procedure for the Configuration of an Inflow Control Device Completion Using Reservoir Modelling and Simulation in the North Amethyst Pool
Authors: Wu Ray , Turpin Allison , MacDonald Dennis , Kavanagh Dion 
Published: June 2014

Abstract
This paper outlines an approach to simultaneously reduce gas and water production through the design and implementation of an inflow control device (ICD) completion for a horizontal production well in the North Amethyst pool. The procedure uses Schlumberger’s Petrel modelling software, Schlumberger’s reservoir simulator, ECLIPSE, and a multi-segmented well (MSW) model to optimally configure an ICD completion within a reservoir model. This approach utilizes the reservoir model to generate ternary plots (oil, gas and water) that represent three-phase movement within the reservoir. The use of MSW enables the dynamic display of a virtual production logging tool (PLT) plot, representing the expected three-phase inflow performance along the wellbore. Both ternary and PLT plots identify the locations of high gas and high water inflow zones along the wellbore.
With these zones identified, various configurations of ICD completions are designed to control these breakthrough zones and are then simulated. ICD equipment options, such as reduced nozzle sizes and blank zones, are considered in the design. The simulation results of the various ICD configurations are compared to determine the optimal design. The design objectives are to optimize oil inflow, oil rate, and ultimate recovery by delaying and reducing gas and water production. The produced liquid rate was also optimized with rate sensitivities for each ICD configuration which led to a design that further reduces gas and water production.
Comparison of Frac Valves vs. Plug-and-Perf Completion in the Oil Segment of the Eagle Ford Shale: A Case Study
Authors: Stegent Neil A. , Ferguson Kip , Spencer Jon 
Published: June 2014

Abstract
Which completion strategy is better—Plug-n-Perf or Frac Valves? The authors of this paper will evaluate multiple completion strategies in two offset horizontal wells drilled in the oil section of the Eagle Ford shale. The first well was completed using a combination of single entry point, ball-activated frac valves (first two-thirds of the lateral) and plug-n-perf (also designated as P-n-P) with multiple entry points (the remainder of the lateral). The second wellbore was completed using only P-n-P with multiple entry points. Both wells were completed using comparable completion designs (hybrid fracture design, number of fracture stages, pounds of proppant, etc.) and were cemented for annular isolation.
To determine the completion and production efficiency, microseismic mapping and oil-soluble tracer technologies were used to evaluate the differences between the completion strategies. Fracture mapping was used to compare stage "complexity," while a hydrophobic oil tracer, which generated a pseudo-production log of each individual stage, was used to determine the completion efficiency.
The integration of these diagnostic engineering technologies allows for interesting conclusions with respect to the fracture complexity generation from the different completion strategies, as well as the resulting production from the comparative wells. This data can provide important information regarding the difference between the two completion methods.
The Full-Automatic Real-Time Display, Testing and Adjustable System in Separated Layers Water Injection Well
Authors: Wang Feng Shan , Xu De Kui , Yu Lei , Zhang Feng Hui , Liu Chong Jiang , Zhu Zhen Kun 
Published: June 2014

Abstract
This paper presents very important water flooding equipment which has been applied successfully in Daqing oilfield in China. This finished product is integrative, intelligent, automatic, real time monitoring, it is a reliable way to collect every layer's pressure, temperature, water injection rate, the testing time, etc., displays and monitors all these data on the laptop screen in real time. The testing workers use the laptop to adjust every layer's water injection rate and all the data records as safely and conveniently as possible. All these recorded data can be used in optimization reservoir development scheme, casing damage monitoring and prevention.
This full-automatic intelligent testing and adjusting equipment system is very suitable for application in poor geological condition, complex oil and water distribution, the single water injection well is separated several layers. Testing, adjusting, recording data can be used laptop to control during the operation. This full-automatic intelligent testing equipment system reduces the working intensity, the testing work-force and the production costs, improves the water injection rate in high water cut-stage oilfield.
This system has been awarded three invention patents and twenty patents for utility model. The single water flooding well testing cost has been reduced 47% in practical application. So far, more than four thousand water flooding wells have been applied with this equipment in Daqing oilfield, totals about six thousand well-times. The testing, adjustable successful rate has been above 85% in one trip, the precision has been increased nearly 10%. The average testing, adjustable time of single water injection well is less than two days which has been more than trebled as against before, the totaled economic benefits is about millions US dollars per year. More than twenty Chinese Oil Production Companies in five different oilfields have applied this equipment.
Production-Data and Pressure-Transient Analysis of Horseshoe Canyon Coalbed-Methane Wells, Part II: Accounting for Dynamic Skin
Authors: Clarkson Christopher R. , Behmanesh Hamid , Chorney Lance 
Published: June 2014

Summary
In a previous study (Clarkson 2009), advanced production-analysis techniques, including production type curves and flowing material balance (FMB), were applied to Horseshoe Canyon (HSC) coal wells to establish the applicability of these techniques and to resolve the importance of multilayer behaviour for production analysis. The field examples chosen for analysis included single wells that exhibited production declines analogous to shallow gas wells, with decline in production occurring from day 1, and in one case exhibiting transient-flow characteristics. There are many more HSC wells that exhibit less-straightforward production characteristics, including flat or even inclining production. These wells have production profiles qualitatively similar to two-phase coalbed-methane (CBM) wells, yet lack water production. There are several possible explanations for the flat or inclining production behaviour, including changing skin associated with near-wellbore cleanup of drilling fluids over time, and increase in absolute permeability associated with matrix shrinkage. Regardless of the cause, these effects need to be accounted for in quantitative production analysis. In this follow-up paper, we continue to perform comparisons between multilayer and single-layer-equivalent production analysis of HSC wells, but focus on wells that exhibit inclining gas production. We develop a methodology to correct for changing skin in both type-curve and FMB analyses that allows this more-complex well behaviour to be analyzed. We validate the new methodology using a simulated example, and then apply it to actual field cases. Changing skin and absolute permeability by layer/coal zone was quantified through periodic shut-in/buildup testing of isolated coals throughout the life of the wells, and these dynamic properties were used in production-data analysis and analytical simulation. Comparing single-layer-equivalent and multilayer analysis, we have found differences in estimated-ultimate-recovery (EUR) values of less than 15% because the existence of one or two dominant (high-kh) coal zones. Additionally, we investigated the impact of free-gas storage on the results of productiondata analysis of HSC wells. The production-analysis methodology introduced in this work, while useful for analyzing HSC coal wells with dynamic skin/permeability, is expected to be applicable to a broader range of reservoir types that exhibit this complex behaviour.
Optimizing the ROI of Digital Technologies in Production Operations
Authors: Prakash Amit , Bansal Aashish 
Published: June 2014

Abstract
Digital Oil field technologies continue to gain ground and lead the march of the oil and gas industry into deeper and more difficult sites for exploration and production. Most of the companies have adopted these technologies, but many have failed to realize their full value due to various reasons, the most common of them being the absence of a process framework to adopt such technologies on a firmwide/ business unit level. As a consequence, companies continue to move into the digital age at a snail's pace largely due to isolated efforts of adopting these technologies by different groups and no firm-wide embedment. This paper recommends a well defined framework to enable the adoption of these technologies at all points of the business process. The framework spreads across the production operations part of the value chain and will enable companies to adopt technologies seamlessly at a faster pace realizing maximum benefits at optimal costs.
Partial-SAGD Applications in the Jackfish SAGD Project
Authors: Li Pingke , Stroich Al , Vink Andrew , Nespor Kristian , Bhadauria Swapnil , McCormack Mike 
Published: June 2014

Summary
With steam-assisted-gravity-drainage (SAGD) operations, there will be times that the producer downhole temperature falls below the desired level. This situation may occur when a shut-in is required because of facility or well operational issues. Cooling bitumen and steam condensate, which continue to drain and raise the liquid level over the producer, cause difficulties with the restart. The producer could also cool if the well pair is converted prematurely from circulation to full SAGD mode.
A variety of artificial-lift technologies have been applied in field applications. However, with its dual-tubing-completion design and gas lift system, Devon has successfully used partial SAGD methods to optimize restart strategies and effectively deal with times when the producer unexpectedly cools.
This paper describes three SAGD operating modes used by Devon at Jackfish: full SAGD, semi-SAGD, and partial SAGD. During partial SAGD, the fluid return from the injector stops while steam injection continues down either the long tubing (LT), short tubing (ST), or the annulus. The producer continues to be circulated with the appropriate steam-injection rate into the LT and fluid returns up the ST. Numerical-simulation results associated with partial SAGD are presented. Partial-SAGD applications at the Jackfish SAGD project are discussed.
Oilfield Data Mining Workflows for Robust Reservoir Characterization
Authors: Holdaway Keith R. 
Published: June 2014

Abstract
"There are more things in heaven and earth, Horatio, than are thought of in your philosophy" "Hamlet" William Shakespeare
To fully appreciate the plethora of disparate data sets across the upstream geoscientific silos, it is essential to establish a sound and consistent suite of workflows that embrace data management facets as well as diverse data mining modules established under the banner of soft computing or artificial intelligence. When does one implement a neural network, a decision tree or non-linear regression techniques? Will Genetic Algorithms or Fuzzy Logic be appropriate for my objective function?
This paper sets out to answer some important questions around data mining workflows underpinned by exploratory data analysis, confirmatory data analysis, descriptive and predictive modeling to establish sound and important reservoir characterization decision-cycles. Case studies are presented to illustrate effective and successful studies based on advanced statistical analysis and AI workflows in sandstone and carbonate reservoirs. Can such workflows be adopted in unconventional reservoirs? Determining accurate and effective hydraulic fracturing packages are keys in tight gas plays, and this paper explicates how data mining workflows can be successfully applied in such unconventional plays.
Sophisticated Software Analysis System and Use of Torque/Drag Modeling for Complex Well Operations Increases Operational Efficiency
Authors: Xie Liangjun , Moran David , Yan Lei , Mercado Jose , Bits Smith 
Published: June 2014

Abstract
Accurate torque and drag (T&D) analysis is a fundamental well planning tool essential for predicting and preventing drilling and completion problems. To guarantee an efficient and safe operation, tension/compression and torque on the bottom hole assembly needs to be controlled within acceptable limits. Practically all available torque and drag software can calculate the following general operation modes: rotating off-bottom, pick-up, slack-off, rotary drilling and oriented drilling modes. However in the well construction process, there are many other complex operational modes that are largely absent from available software systems, as discussed in the literature. The industry requires modeling methodology to analyze complex well operations including: setting and un-setting packers, anchoring liner hangers, shearing pins in wellbore departure operations, loading and operating drilling/fishing jars in both overpull and compression.
The authors will discuss new modeling software capable of analyzing complex well operations including liner hanger and jarring operations in detail. Further discourse about how modeling these special operations were combined with field experience and confirmed the accuracy of the new module with regards to both special operations and conventional T&D capabilities. The simulation/analysis recommendations were successfully executed in the field and led to increased operational efficiency and unplanned cost avoidance. Case studies will be presented of successful liner hanger deployment and complex drilling jar simulation.
Smart Metering: An Online Application of Data Validation and Reconciliation Approach
Authors: Haouche M. , Tessier A. , Deffous Y. , Authier J-F. , Couput J-P , Caulier R. , Vrielynck B. 
Published: June 2014

Abstract
The availability of reliable data is obviously a prerequisite to good production optimization. So far, many tools have been developed to increase the availability of data by using Smart Completions, Downhole Measurements and Remote control Sensors installed along the production chain. The progress in production models has also contributed to this improvement. Nevertheless, in term of reliability, the collected data are affected by uncertainties, which must be taken into account.
The process of Data Validation and Reconciliation (DVR) considers all the relevant information (measures/ models) of the production plant as one integral set of parameters. Furthermore, the originality of DVR as compared to equivalent systems is the use of a statistical model to control uncertainties associated with each parameter, and calculating the resulting error propagation. As results and thanks to the information redundancy, DVR allows an automatic real-time correction of each parameter based on its allocated uncertainty.
In this paper, we focused on a real time application with 16 Wells belonging to 3 offshore Platforms. The single-Well model is initially validated by using the Multiphase Flow Meter (MPFM) measurements.
The global results analysis is discussed by comparing the online application outputs with production tests using MPFM, in terms of Oil flow-rate and Water Liquid Ratio (WLR). Also, the monitoring of each information is highlighted in order to detect a model deviation or instruments failure. Furthermore, the error distribution is used to identify the impact of any deviation occurring in the application.
Conclusions are drawn on the performance of the virtual metering system in terms of online availability, results reliability and global consistency between data and results. The DVR application is considered as an operational monitoring tool thanks to alarms which are customized by operators, and as an analysis tool for investigation and diagnosis studies.
Improving Oil & Gas Installation Safety through Visualization of Risk Factors
Authors: Braseth A. O. , Sarshar S. 
Published: June 2014

Abstract
This paper presents the second version of the Maintenance and Modification Planner (IO-MAP). IO-MAP is a software tool designed to reduce risk in job planning on offshore oil & gas installations in an Integrated Operations (IO) setting. In this situation the planner is likely to have reduced knowledge of the actual installation, and the intention of the IO-MAP is to support the operator in safe job planning through visualization of risks on the actual installation. Risks such as hot work, potentially falling objects, workload and weather data are visualized. The new version is intended to support multiple users planning offshore jobs on a shared large projected display. It is an evolutionary design, based on feedback from exploratory studies on the first version. The studies on the first version identified several improvement areas were parts of the design was too complex and abstract. The new version of the tool described in this paper, has redesigned several objects to be more intuitive and less abstract. The colour scheme has improved consistency for easier comparison of risk factors on the installation. New functionality related to risk factors is also included. The graphical design scheme is inspired from Information Rich Design used in other applications such as large screen displays for oil & gas process monitoring in Norway.
Energy Company Perspective on Virtual Worlds / 3-D Immersive Environments
Authors: Morneau Richard A. , Van Herreweghe Williams G. , Little Joe W. , Lefebvre Dominique B. 
Published: June 2014

Abstract
Many industries, including the Energy Industry, are leveraging virtual world based technologies to enhance training and situational understanding. The phrase "a picture is worth 1000 words" is implicitly understood because "seeing" helps crystallize concepts making more transparent the ambiguity of the spoken word.
Virtual Worlds are 3-D immersive environments, which allow workers to perform tasks and collaborate within a virtual representation of their normal work environment. Virtual world technologies represent a step forward in understanding work process complexities within a collaborative environment providing workers with the ability to be active participants, through their avatars, within a virtual representation of the world in which they work.
Achieving operational excellence requires a broad, holistic view of all operational aspects. Current state-of-the-art methodology calls for assembling various data feeds into complex dashboards, which may not bring clarity to operational situations. And, dashboards do little to help one understand the implications associated with various work processes behind the data feeds. While dashboards are a step in the right direction and are certainly better than having to find the information in different isolated systems they still fall short in providing operational awareness for complex multifaceted work processes. This is especially true in our facilities, which are large complex environments. New facilities and major capital projects present their own opportunities. Our challenges are further complicated by our multinational workforce, which does not have a single common first language. Work done at Harvard University has found that virtual world technologies offer advantages in these circumstances for learning.
Operational excellence is brought about by operational awareness. Operational awareness is brought about by seeing and interacting with the data within its proper context. This paper will present how virtual reality based technologies can reduce ambiguity and enable contextual operational awareness which helps achieve operational excellence, illustrating that seeing and doing within the work process context increases understanding. The digital oilfield and digital plant can be intelligently exposed with virtual reality technologies.