bluuebunny/crossref_metadata_2025_split huggingface dataset:
Application of Reservoir Characterization Synthetically Applied With Ant Tracking and Geological Statistics Inversion in Offshore Oilfield Development: A Case Study of CFD11-X Oilfield in Bohai Bay Basin
Authors: Wei Yang , Qingyun Bai , Peng Meng , Guangming Pan , Chuanqi Liu 
Published: September 2016

Abstract
CFD11-X is an offshore oilfield in Bohai Bay Basin. Since the drilling data is less and the resolution of seismic data is not high in the deep, our knowledge to the fault system and sand bodies is not sufficient. During the implementation of overall development plan (ODP), it gradually exposes the problems that the prediction errors of sand bodies and fluid system are serious for some development wells and the geologic risk is underestimated. These problems make the ODP less effective and cause some wastes of investment directly.
To solve the problems, the authors applied ant tracking algorithm and geological statistics inversion synthetically in reservoir characterization study. On one hand, we apply ant tracking algorithm to identify the faults which are too complex and indistinct to be interpreted manually. On the other hand, we apply geological statistics inversion to describe the distribution of sand bodies. After that both the faults and sand bodies are extracted and overlaid together. By use of multiple materials and methods, we analyze every fault to classify and screen them in both "possibility of existing" and "influences on oil in place and oilfield development" aspects. With the new perception of fault system and sand bodies, we build geological models to improve the geologic risk prediction. Finally under the guidance of our study, both the geologic risk and potential of each well to be implemented in ODP are reevaluated and optimized. Recently we choose two of the wells as pilot tests. It is confirmed by the two wells that our prediction of the sand bodies and fluids are both quite accurate with the guidance of reservoir characterization study.
In the context of the current low oil price, our study effectively reduces the cost of development, decreases the investment risk and increases the return of investment.
Transforming the World of Asset Management in Near Real-Time Using an Intelligent Application to Optimize Daily Production Operations
Authors: Gupta Supriya , Kansao Rami , Saputelli Luigi , Escorcia Alvaro 
Published: September 2016

Abstract
Operators nowadays are swimming in huge terabytes of data through continuous data acquisition and permanent reservoir wide surveillance but will little intelligence to identify and decrypt key obstacles, challenges and constraints to sound asset management. Silo-ed organizations and short-term blindness offer limited opportunities to understand reservoir performance in real-time and its associated challenges and therefore minimize opportunities for production enhancement and value creation. This paper discusses a novel application which can help E&P operators in implementing best practices towards continuous monitoring of daily production operations to better understand and address key issues related to production performance from upstream to mid-stream. It offers a unique data-model coherent with Petroleum Production Data Management (PPDM) guidelines, built-in logic to determine actionable key performance indicators (KPI's) to measure asset performance, and interactive and collaborative dashboards to identify key challenges and bottlenecks to sound asset management and opportunities to enhance production and improve operational efficiency. The proposed visual solutions can decrypt constraints from reservoir to surface and mitigate these challenges by discovering and diagnosing the issues in real-time. In this manner, this application can facilitate exception based surveillance which is becoming an integral part of operating philosophy for E&P companies (Kumar 2013). It was proven that this application helped reservoir and production engineering teams achieve higher success in production transformation initiatives for capturing daily operations which are not detectable by traditional engineering analysis and reservoir simulation production forecasts.
Carbon Quantum Dots Fluorescent Tracers for Production and Well Monitoring
Authors: Murugesan Sankaran , Kuznetsov Oleksandr , Suresh Radhika , Agrawal Devesh , Monteiro Othon , Khabashesku Valery N. 
Published: September 2016

Abstract
Tracer technology is a very efficient diagnostic tool for the oil and gas industry to obtain valuable information about reservoirs. The interpretation of tracers that have traversed the reservoir reveals reservoir characteristics such as inter-well connections, heterogeneities, and water movements that can be used to improve hydrocarbon recovery efforts. Commonly used tracers are radioactive elements and stable isotopes, chemicals, such as fluorescent dyes, and inorganic ions. Novel carbon quantum dots (CQDs)-based fluorescent tracers have been proposed for production and well monitoring. One-step electrochemical synthesis of CQDs from low molecular weight chemical precursors through electrochemical carbonization was developed. The doping of CQDs with heteroatoms such as nitrogen provides differentiated fluorescence emission signatures that can be used to monitor multiple stages of frac operations.
Pushing to the Extreme—Microseismic Monitoring of Hydraulic Fracturing in an HP/HT Horizontal Well in the Sultanate of Oman
Authors: Briner Andreas , Nadezdhin Sergey , El Gihani Mahmoud , Al-Wadhahi Taimur , El-Taha Yasin Charles , Harrasi Othman , Kelkar Shrihari 
Published: September 2016

Abstract
In the last 3 years, Petroleum Development Oman (PDO) went from failure to success with microseismic monitoring of hydraulic fractures in deep, high-pressure/high-temperature (HP/HT) horizontal wells. The most recent operations were performed in the conditions of the highest complexity to date.
The hydraulic fracture monitoring (HFM) was performed in the 69° deviated section of a horizontal well with the geophones conducted on wireline. The perforation shots for velocity model calibration were performed through casing with no cement behind (a feature of the treatment well completion), which has not previously been documented in publication. A new generation of microseismic geophone shuttles was used on the stinger with two knuckle joints to enable passing through the high-dogleg sections of the well.
The geophones spent up to 12 hours downhole in one run with no signs of failure. The sensor array was successfully deployed on the first attempt in all runs in the highly deviated well section. Four fracturing stages were monitored, yielding hundreds of good-quality microseismic events. This provided enough data to evaluate the fracture geometry and complexity, symmetry of fracture wings, diversion efficiency of swell packers, and the number of fractures initiated in the same stage and their propagation. All this provided input for meaningful comparison of the openhole completion with previously completed cased holes. This data will guide future field development, well count, well spacing and will enhance the fracturing design of any future wells.
Hydraulic Fracturing Treatment Design Considerations for Effective Proppant Pillar Construction
Authors: Gomaa Ahmed M. , Hudson Harold , Nelson Scott , Brannon Harold 
Published: September 2016

Abstract
As an alternative to conventional proppant pack placement, propped pillar-fracturing promises more effective and conductive fractures that enable hydrocarbons to flow through open channels. Recent experimental and numerical studies confirmed that viscous fingering phenomena can be used to develop a proppant pillar-fracture type placement: High-viscosity, proppant-laden fluid can be placed, and then a low-viscosity clean fluid is pumped to carve pathways through the proppant-laden fluid in a dynamic, continuous process. However, the created channel pattern was found to be significantly dependent on fracture geometry and treatment design parameters such as injection rate, fluid pulsing time, and fluid viscosity ratio.
The objective of this study is to extend the numerical investigation and normalize it to develop a treatment design methodology for constructing proppant pillars throughout the created fracture. A computational fluid dynamics (CFD) model was constructed using commercial CFD software, simulating the flow of fluids inside the fracture and the resulting proppant pillar generation. The study focused on the effects of surface injection rate (1 to 40 bpm/cluster), pulsing time (5 sec to 5 min), and viscosity ratio (from 2 to 20) between the two injected fluids to develop correlations between these parameters and the created fracture geometry.
Based on numerical results, the viscosity ratio chosen to achieve the proppant pillars allows the use of conventional crosslinked fluid without a hindered settling agent. In these designs the settling of proppant into pillars can be made to occur after the end of the stimulation treatment. Controlled settling of proppant from a crosslinked proppant-laden slurry allows channel formation and creates wider propped fracture-width pillars as compared to current industry pillar-fracturing treatment techniques. The optimum channel pattern has small channel sizes, remains open under closure stress, creates more channels throughout the entire fracture area and maintains good communication between unpropped areas. A new dimensionless term, Dimensionless Stage Volume (VSD), is presented to describe the channel pattern inside the fracture. Smaller VSD numbers resulted in smaller and more distributed channels. Therefore, it is highly recommended to select and design a proppant pillar-fracture treatment to achieve the lowest VSD possible and create the optimal channel pattern.
Integrated Gas Development Planning in Southern Iraq
Authors: Karnik Amit A , Gupta Arjit , Wharton Mark , Henry Herve 
Published: September 2016

ABSTRACT
Maximizing the value of a significant gas resource base in southern Iraq for all key stakeholders is complex, driven by a number of key challenges on both the supply and demand-side of field development. The majority of the future gas supply in the south of Iraq will come from associated gas from some of the world's largest oil fields including Rumeila, West Qurna and Zubair). Successfully utilising the gas for industrial and domestic supply requires integration across upstream, midstream and downstream business segments and cooperation between multiple parties from the Government of Iraq (GoI) and the field operator contractor consortiums in Iraq.
Some of the main challenges that the Iraq Oil & Gas industry faces today are lower commodity prices impacting the availability of investment capital, weak fiscal incentives for gas production, inadequate integrated gas infrastructure development, limited cross-industry gas planning and coordination & limited new exploration activity. The above issues also cary an overlay of environmental and security conditions, meaning that fully integrated development planning and decision framework modelling needs to be at the core of mapping the most attractive way forward for future investments.
This paper presents an integrated workflow approach that allows modelling & assessment of the impact of technical as well as non-technical risks and uncertainties in a systematic manner along the value chain at a number of different nodes. This model follows the hydrocarbon molecules from the reservoir through to the downstream petrochemical plant enabling assessment of a potential range of scenarios across upstream, midstream and downstream.
In a region where uncertainties go far beyond the technical domain, this approach allows decision makers to navigate through the potential outcomes and formulate integrated roadmaps and development strategies. It also identifies the benefits of an integrated development approach across fields developed by different contractor consortiums. The workflow facilitates; Analysis of the current gas landscape and identification of priorities, with a focus on what could be done to increase gas supply in the short to medium term;A vision for longer term gas industry development and provides guidance on nature and timing for future infrastructure required to realize this visionIdentification of key enablers to expedite gas growth in the wider southern Iraq area.
A Road Map to Improve Coiled Tubing Well Intervention Services
Authors: Ginest N. , Al-Nuhayan F. , Ashby S. , McClelland K. , Phillips J. , Green T. , Winkleman D. 
Published: September 2016

Abstract
Saudi Aramco performs over 900 coiled tubing (CT) well intervention operations annually on oil, gas and water wells. To improve service quality and reduce incident frequency, Saudi Aramco has focused on developing internal resources, setting realistic standards and assessing service providers. Sharing the processes followed, lessons learned and reoccurring service quality issues should be of value to the practicing engineer.
Saudi Aramco has developed a comprehensive CT well intervention program with the goal of ensuring that all CT operations are conducted safely and effectively. The foundation for this integrated, knowledge and quality based CT well intervention program was built on the following principal components: The compilation and periodic revision of two comprehensive internal reference documents – the Saudi Aramco CT Manual and the Saudi Aramco Standards for CT Services. These documents are applicable company-wide for rig based and rigless CT operations in oil, gas and water wells. The manual and the standards focus on safe CT operations and maintaining full control of the well with multiple redundant closed and closeable barriers.The commitment of Saudi Aramco's Upstream Professional Development Center (UPDC) to be an industry leader in the accelerated training and development of upstream professionals. UPDC's instructional design experts worked closely with internal and external subject matter experts (SMEs) to design CT courses to enhance learning and maximize relevance to job designs and operations taking place every day within the company.A program to conduct comprehensive technical and quality management system (QMS) assessments of well intervention service providers was initiated to address concerns about the quality of the well intervention services provided by both current and future providers and to ensure that operations are conducted safely.
The program was initiated over 15 years ago and has grown and evolved based on advances in the industry and lessons learned internally. What started as a narrowly focused manual to cover CT operations in high pressure gas wells has expanded substantially to include all CT operational categories, training, quality management systems and assessments. This paper will discuss details of the implementation of the three primary components of Saudi Aramco's integrated approach. Statistical trends of CT failures will be presented as a measure of the program's success, and the results and an analysis of the findings from the comprehensive CT service provider assessments will be discussed.
Instituting technical and quality standards, measuring compliance with these standards by performing periodic assessments, and providing training for the end users have resulted in lower incident rates and better delivery of service related product.
Evaluation and Development of Complex Clastic Reservoirs using NMR
Authors: Hursan Gabor , Silva Andre , Zeghlache Mohamed L. 
Published: September 2016

Abstract
Several light oil and gas reservoirs are present within an extensive Permian clastic sequence in the Middle East. Well logs and core data revealed numerous challenges for the petrophysical description of this formation. Rapidly changing depositional environments and diagenetic effects caused heterogeneities in grain size and sorting within clean sands. Consequently, gamma ray and conventional porosity logs have little sensitivity to rock quality variations. Secondly, an influx of meteoric water into the reservoir rocks decreased formation water salinities which adds uncertainties to the estimation of fluid saturations from resistivity logs. Finally, gas-oil contacts are present in some reservoirs where log-based in-situ hydrocarbon typing is of great practical value. The introduction of nuclear magnetic resonance (NMR) logs has successfully mitigated these issues as evidenced by petrophysical interpretations and formation testing in the area's exploration and delineation wells.
Lateral facies variations and complicated reservoir structures warranted the deployment of NMR technology in horizontal development wells for better well placement and completion optimization with logging while drilling (LWD) NMR as the most preferable option. The NMR logs led geosteering decisions and proactive well planning to singificantly increase reservoir contacts in producer wells. Permeability predicted by the NMR logs is of great value in real-time well placement decisions and completion design including ICD installations. The low-gradient LWD NMR measurement gives rise to a very simple and robust real-time fluid identification thanks to the the good separation of water and oil signals in the NMR T2 spectrum. This fluid quantification, combined with bound fluid analysis, helps determine the well's position in the transition zone by detecting free water.
This paper summarizes the experience with both wireline and LWD NMR technologies in the area. Lessons learned include considerations for deployment, tool activations and NMR interpretation.
Loose Coupling of Metadata and Actual Data in End-to-End Data Provenance
Authors: Rundle R. T. , Vuurboom R. , Monroe B. V. 
Published: September 2016

Abstract
In a distributed object system, metadata provides a concise description of the object that can be distributed broadly. The actual data that represents the complete object is often very large and hence can be time consuming to transfer. Metadata is an enabler for the wide area distribution of objects along potentially unreliable and low speed channels. The metadata could go first and the actual data would follow only if needed.
Data provenance is the chronology of an object, i.e. a record of all of the transformations and actions that modified the state of the object from the time of creation to the present time. End-to-end data provenance is the ability to account not only for the data provenance of a single object, but also to account recursively for the data provenance of all other objects that affected the state of the object.
Loose coupling of metadata and actual data is well understood for static, unchanging data. Systems across many industries allow remote browsing of metadata representing huge datasets and the selective movement of actual data. For example every content delivery network (CDN) employs loose coupling of metadata and actual data to deliver movies, videos, books and other types of static data.
The problem yet to be solved is the one in which the actual data is changing over time. This is an important use case in shared earth problems. As modeling of the subsurface increases and is used by larger, more geographically disperse teams, there is a need for a system that supports the special requirements of shared earth modeling. These requirements include the need to support parallel changes to objects, support for slow and unreliable networks, and the ability to work disconnected from a central repository. Such a system is presented in this paper. This paper is a follow on to SPE 174803, End-to-End Data Provenance.
Determination of Oil Well Production Rate by Analysis of the Real-Time Dynamometer Card
Authors: Han Guoqing , Tan Chaodong , Li Jun , Pan Zhejun , Zhang He , Ling Kegang 
Published: September 2016

Abstract
Real-time data collection, processing, and surveillance are critical in field operations for monitoring well production and assessing effectiveness of well workover and intervention. Conventional metering strategy is unable to keep up with the requirement for continuous and real-time measurement. For marginal fields, surface facility is often shared among many wells due to its high cost. In this paper, an innovative technology is proposed to analyze dynamometer card collected from a SCADA system and accurately derive the individual well production rate in real time.
By solving wave equations, the developed system converts the surface dynamometer card to a downhole dynamometer card, which can be analyzed to locate the travelling valve opening and closing points. With non-linear and unconstrained optimization, this technology can accurately determine the effective stroke and liquid leakage, and consequently obtain the production rate.
The proposed method has been successfully applied to 170 oil wells with an average measurement error of only 6.66%. It works well for both vertical and deviated wells, and for both light and heavy crude fluid. This digital energy technology can be used not only to determine the production rate for individual wells in real-time, but also to decrease operational expenditure, which can significantly improve the cash flow for managing marginal fields in the current low oil price environment.
Oil Price Shocks: A Measure of the Exogenous and Endogenous Supply Shocks of Crude Oil
Authors: Economou A. , Agnolucci P. 
Published: September 2016

Abstract
The paper introduces a new measure that jointly identifies and disentangles the oil supply shocks of crude oil into exogenous and endogenous, by quantifying the positive and negative shocks to oil production caused by events outside the oil market (exogenous) or as a consequence of the normal functioning of the oil market (endogenous). The objective is to examine how the use of alternative measures of oil supply shocks affects our assessment of the dynamic effects of supply shocks on the real price of oil since 1990. Results show that for most of the 1990s, shortfalls in oil production that were brought about by geopolitical episodes accounted for about 7% of the variability in global crude oil production. However, this pattern reverses after 2000 onwards, as fluctuations in global oil production are largely attributed to market-specific events (6%). We show that oil supply shocks may have very different effects on the real price of oil, depending on the underlying specification of the shock. In particular, the measures that capture market-driven shifts in oil supply are found to be more plausible than the rest in explaining the variability of the real price of oil, especially when compared with flow supply shocks. In fact, analysis suggests that flow supply shocks underestimate the historical contribution of oil supply shocks to changes in the real price of oil, in contrast to total supply shocks that appear to have exerted significant upward pressure in the real price of oil especially between 2003 and mid-2008. Overall, endogenous supply shocks play an increasing important role in the historical evolution of the oil price, but it must be noted that oil price developments after 2010 are largely attributed to exogenous supply shocks. We conclude that historically the supply side of the market has been an important determinant of the real price of oil after all.