bluuebunny/crossref_metadata_2025_split huggingface dataset:
Investigation on the Suitability of Virtual Flow Metering System as an Alternative to the Conventional Physical Flow Meter
Authors: Varyan R. , Haug R. K. , Fonnes D. G. 
Published: October 2015

Abstract
The interest in Virtual Flow Metering (VFM) has been increasing as awareness of its capabilities and benefits as an alternative or backup to the conventional physical flow meters evolves. Despite the fact that the technology has been in operation for more than 20 years, the adoption of this metering technology remains slow, particularly in Asia Pacific region. Virtual flow metering system provides real-time production monitoring of wells. A fine-tuned model and sufficient well instrumentation can also detect water breakthrough in the gas production well or gas coning in an oil producer. The main objective of this paper is to improve the general understanding of virtual flow metering technology and provide a basis to evaluate if implementation of VFM is a suitable alternative to conventional physical flow metering for a given system.
The VFM technology is based on an online (real-time) steady state multiphase flow simulator (thermo-hydraulic models) of the field, where flowrates are estimated using a powerful multivariable optimization solver. For individual wells, the model typically includes the production system from reservoir up to commingling point, e.g. manifold. Successful utilization of virtual flow metering technology is dependent on the availability and accuracy of instrumentation. Model tuning also plays a critical role in a VFM system as it is required to compensate for changes in the system and fluid characteristics throughout the life of field. This paper exemplifies a case study to show how the accuracy of VFM might change over time and the importance of performing model tuning regularly.
Strategic Handling of Stranded/ Associated Gas During Oil and Gas Exploration - A Case Study on a South East Asia Field Model
Authors: Sankararaj Rubakumar , Mirzaee Farnoosh , Wadsley Andrew 
Published: October 2015

Abstract
This paper presents a complete integrated asset model for gas planning and, in particular, the handling of stranded gas during exploration. Uniquely, it models a gas network from the reservoir, right through to product allocation based on contractual obligations. It back-allocates through the network from the market, to ensure accurate supply and product tracking. We show how this type of model provides unprecedented confidence in field evaluation and gas planning.
The market-based approach to integrated asset modelling that we used includes an optimal amount of information to deliver a fast, accurate solution. Oil and gas exploration activities do not usually involve planning for stranded or associated gas. Many discovered gas reservoirs are left undeveloped due to a lack of scenario analysis during the exploration phase. A fully integrated gas planning approach is required for effective field development planning in a timely manner. This has been a subject of intense research and development in recent years. Stranded gas reserves can be effectively developed using proactive market planning and strategic gas exploration guided by an integrated gas planning approach. As such, our model includes reservoirs, platforms, facilities, pipelines and markets to effectively understand the network deliverability.
In this paper we defined multiple scenarios for bringing up gas from reservoirs, through the facilities and delivery point, right up to allocation of resources to meet the market demand. The case study deals with a market-based approach for modeling 40 gas reservoirs and associated gas products from nearby platforms. The practical constraints such as condensate handling capacities, compressor systems, and contract gas quality are integrated into the model analysis.
The unique, fully integrated reservoir to market approach to IAM we demonstrate in this study provides a real breakthrough in E&P companies’' ability to model and run scenarios against their complete gas network in a relatively very short time. In particular the back-allocation from the market provides confidence around their ability to meet their contractual sales obligations and enables product tracking through the whole network.
New Multilayer Boundary Detection Service Employing in Complex and Mature Reservoir of Bohai Bay, Northern China
Authors: Guo Xija , Jia Yong , Fan Kai , Yang Liuhe , Zhao Guoquan , Wu Kai , Wang Fei , Li Cang , Gao Zhujun 
Published: October 2015

Abstract
Bohai Bay basin, the largest offshore basin of China, is located in northern China. Its oil and gas resources are commercially operated by China National Offshore Oil Corporation (CNOOC) since 1967. From 1967 to the present, more than 100 production platforms have been put into operation in a 43,000-km2 exploration area, including both development projects on the greenfield and infill projects on the brownfield.
The predominant depositional environment of Bohai Bay basin is a shallow delta and a meandering river system complicated by faults, which leads to fully developed interbed interference and high geological uncertainty while drilling horizontal wells within the greenfield. For the infill projects, high water cut is the primary concern, especially after long-term development. Therefore, our trajectory must be controlled precisely in a desired position to overcome the existing or potential water issue. As a solution to these challenges, a new multilayer boundary detection service has been introduced to CNOOC for the first time.
Outstanding outcomes have been observed by implementing this new multilayer boundary detection service. This innovative technology was applied to two challenging wells, well A of a development project achieved 377m measured depth (MD) lateral exposure with 100% net-to-gross (NTG) while depicting whole individual sand bodies and their mutual lateral contact relationship clearly, which not only can optimize the final NTG but also supply much detail, allowing for a more robust reservoir characterization. By using this technology on both landing and lateral section drilling for Well B of the infill project, target top was identified 3m true vertical depth (TVD) in advance and landed less than 1m below the target top with very low incident angle. Precise landing and lateral placement of horizontal wells and the use of inflow control devices for completion, have become critical to the success of this campaign. The results have shown that water cut has significantly declined from an average of 46.2% to 2.1%. This considerable decline can can bring higher recovery rate to this brownfield.
Even for the entire China market, this was the first time that the new multilayer boundary detection service was introduced. This paper illustrates an exemplary case study of using this innovative technology for a better understanding of reservoir characterization and higher recovery rate while performing high quality geosteering in complex and mature reservoirs.
Experience and Lessons Learned to Increase Job Success Rates for Hydraulic Fracturing in the High-Temperature Lower Pematang Sandstone Formation
Authors: Rahayu Sri , Subiantoro Edy , Hafizh Gama 
Published: October 2015

Abstract
The Lower Pematang Formation is a high-temperature sandstone reservoir (up to 350 degF) in the Central Sumatra Basin in Indonesia. It is a low-permeability reservoir (0.5 to 3 mD), and so oil flow rates are often sub-commercial, despite high initial reservoir pressure and gas-lift.
The obvious method to improve oil rates and recoveries in this reservoir is hydraulic fracturing.
The 1st campaign of Hydraulic fracturing was conducted in 2008 (2 wells), the 2nd campaign in 2009 (3 wells), the 3rd campaign in 2011 (2 wells) and the latest campaign was in 2014 (3 wells).
During the Frac Jobs, the team experienced operational problems due to high bottom-hole temperatures of 320 degF at 7000 ft. depth.
When pumping frac fluid at higher rates, the frac-packer released and jumped up because of thermal shrinkage of the frac string. It happened in the first campaign in MSDC-08, and again in the 2nd campaign in MSDC-10, where the pressure surge also burst the casing.
After the first packer release, the frac string was redesigned to include a 10 ft. expansion joint. Yet the second packer failure still occurred. After considering a safety factor, the team added a second 10 ft. expansion joint to overcome worst-case elongation and shrinkage effects. In addition, the team kept the annulus pressure at 500 psi to maintain downward force on the packer.
Another well integrity problem caused by high bottom-hole temperature was out-of-shape casing, whereby the production packer or cement squeeze packer could not be set at the desired depth. So, casing selection is very important to support future frac jobs.
Pre-frac CBL and Caliper logs also are important to identify poor cement bonds and out-of-shape casing, as frac job success needs cement isolation and a smooth casing face.
Once these elements were all achieved, the frac-job success rate approached 100%.
This paper will take the reader through a journey of frac failures, design changes, more failures and then finally on the road to success.
Economic and Operational Analysis of Systematically Deploying New Technologies in an Unconventional Play
Authors: Van Sickle S. , Galloway J. , McClellan C. , Snyder D. 
Published: October 2015

Abstract
An operator working in the STACK and Mississippi Lime plays of the Mid-Continent region in the United States is developing its acreage with the use of open hole multistage (OHMS) completion systems. This paper will detail new technologies and advancements that are providing enhanced economic benefits and enabling the operator to unlock the full potential of the targeted formations.
The operator holds one of the largest acreage positions in the Mid-Continent region and in 2014 had operated or participated in approximately 170 horizontal wells. This operator approached its development with the goal of reducing completion costs; bringing completion costs in line with estimated completion costs; reducing health, safety and environment (HSE) exposure, while reducing cycle time; and preserving estimated ultimate recovery (EUR) of its assets. Some of the new technologies and advancements to achieve these goals include: changing core completion methods, dissolvable balls, microseismic analysis, water-soluble tracers, oil-soluble tracers, stage spacing and statistical analyses.
These new technologies and advancements adopted by implementing OHMS completion systems provided the operator with significant cost savings when compared to previous wells completed in the region using cemented liner plug-and-perf techniques. Lessons learned from each well were applied to future wells and the operator realized further cost savings as it continued development of the region using OHMS completion systems. These cost reductions were achieved while preserving the EUR of the assets, increasing the economic viability of the operations.
The technologies, methods and procedures will be presented in this paper to help paint a picture of how this particular operator is leading the way in reducing completion costs and increasing reserves. The details provided will show how OHMS technology is a cost-effective option for operators drilling and completing horizontal wells in the Mid-Continent region of the United States and provide strategies that can be applied in other formations around the world.
CO2 Sequestration in Unmineable Coal Seams
Authors: Ibrahim Ahmed Farid , Nasr-El-Din Hisham A. 
Published: October 2015

Abstract
Carbon dioxide (CO2) is a major greenhouse gas that is emitted in all activities. CO2 sequestration in coal enhances methane production from the coalbed (ECBM) in addition to storing CO2. CO2 can be stored in coalbeds in three ways: free gas within the pore space or fractures in the coal, adsorbed on the organic surface of the coal, or dissolved in the groundwater within the coal.
This paper addresses the effect of the salinity of the coal seam water, injected gas composition, and formation pressure on the CO2 sequestration in volatile bitumen coal. In order to achieve these objectives, coreflood tests were conducted using coal cores. The displacement efficiency of water by CO2 and the effective water permeability change due to CO2 adsorption were measured.
The coreflood experiments showed that the permeability reduction due to coal swelling was significant in the case of high NaCl concentrations. The permeability reduction changed from 22 to 32% with the salinity increasing from DI to 20 g/L NaCl. The displacement efficiency increased as the salinity increased. The water saturation after CO2 injection decreased from 37 to 25% with salinity increasing from DI to 20 g/L NaCl. Also, as N2 concentration increased in the injection gas, the permeability reduction and the sweep efficiency decreased. In the case of DI water and 50% N2, the permeability reduction was 12%, and the residual water saturation was 47%.
Based on these observations, CO2 sequestration and ECBM into highly volatile bitumen coal seams with high salt concentration is more efficient compared to low salt concentration.
Reducing Delays in Document Management and Tooling Costs of Refineries and Plants: A Case Study of Risk Management Software Development
Authors: Simonetti Riccardo , Ciccone Giacomo , Ferrante Andrea , Daher Elie 
Published: October 2015

Abstract
ENI SpA was facing a persistent challenge in one of its Italian Oil/Gas treatment plants due to the time-consuming task of equipment, personnel, and on-site operation document management that increased the tooling costs of their operations. The company decided to explore new technologies, systems and services to solve this issue and reduce associated costs. Servizi Integrati di Sicurezza Srl, part of United Safety Group, was tasked to develop a tool to facilitate all safety operations and regulatory aspects of the standard and non-standard activities.
Following the concept of Software as a Service (SaaS), a risk management software was designed to improve document release, tracking, recording, and operations management. The software was designed to allow users to manage multiple projects including bill books, law fulfilments, documents, forms, work permits, access control and any other activity-related document management. The system also allows remote control and access to documents thus serving as a monitoring tool independent of operational dynamics in the plant.
The system performed plant access management for all personnel and equipment. It provides personnel tracking for quick emergency response and has integrated Radio-Frequency Identification (RFID) fixed readers and validations on computers or tablets. It stores over 100 profiled ad-hoc checklists and controls thousands of work permits every month, classified by areas, types of work, contractors, foreman, and time schedule. Using the software, the management was able to accomplish its safety management system and was able to generate reports by correlating several data and information. The software now acts as a connected business intelligence platform providing interactive views and statistics of the data for HSE management supporting Simultaneous Operations (SIMOPS) to avoid unwanted and costly operational interferences.
Prior to using this software, plant managers used separate project files focusing on specific operations such as work permits, personnel checklists, access control, etc. The result was a vast and fragmented management that increased risk exposure due to the high human activity rate. This case study shares the key metrics and costs savings of having a system that functions as a global container for safety data that allows automated actions and advanced controls.
Development and Application of an Efficient Geosteering Tool for CBM Drilling
Authors: Gao Wenkai , Dou Xiurong , Yang Hui , Wang Lei , Zhang Liancheng , Li Lin , Chen Wenyi , Peng Liexin , Wei Zhigang , Shi Rong 
Published: October 2015

Abstract
In CBM drilling, high-efficient, low-cost MWD and geosteering tools are needed to ensure the cost-efficiency of large-scale gas development. Especially in a cluster and horizontal coalbed methane well drilling environment, one of the most effective methods to enhance the individual well producing rate is to keep the bit always in the best position to extend along the target layer.
The DREMWD CBM drilling geosteering system adopts electromagnetic information transmission technology. Compared to traditional mud pulse technology, it has such advantages as a wide range of media applications, deep non-relay transmission, a fast signal transmission rate, and a low failure rate of field applications. Moreover, it can measure wellbore trajectory and geological parameters, so as to ensure actual wellbores to penetrate into coal seams and get the best position. Therefore, it has quickly become a leading geosteering tool for CBM drilling.
The DREMWD system consists of downhole tools and surface units. Downhole tools are mainly composed of the high-power generator, orientation sensor, natural gamma sensor, electromagnetic transmitter circuit, insulation transmitting antenna, and non-magnetic drill collar. Surface units are mainly composed of the signal receiver, ground antenna, driller display, and signal processing and analysis software. With its unique high-power downhole generation technology, greatly enhancing emission intensity and formation penetration. The rotary dynamic azimuth natural gamma measurement module is composed of a natural gamma sensor, a rolling angle sensor and a signal processing circuit. It can perform real-time measurement of the formation natural gamma within a certain fan-shaped range at upper and lower levels. The system has been widely used in the CBM drilling in Qinshui basin in China with good effect.
With this geosteering tool, the drilling performance and recovery efficiency have been remarkably improved. This paper will highlight the technical development and present helpful case histories and recommendations.
CO2 Storage Assessment in Offshore Northern Australia - Is There Potential for an International Carbon Capture and Storage Project?
Authors: Consoli C. , Nguyen V. , Higgins K. , Khider K. , Lescinsky D. , Morris R. 
Published: October 2015

Abstract
Several offshore sedimentary basins around Australia have been assessed as potentially prospective for CO2 geological storage. A recently completed detailed assessment of one of these basins, the Bonaparte Basin, offshore northern Australia, indicates that the Mesozoic-aged deep saline formations forming the Petrel Sub-basin, a major structure element of the Bonaparte Basin, are highly prospective for CO2 geological storage, and represent suitable depocentres for regional emissions.
Petrophysical, seismic and facies analysis shows that the deep saline formations comprise multiple high quality reservoir-seal pairs. A basin-scale geological model indicates that migration-assisted storage (MAS) is the primary trapping mechanism due to long migration pathways (up to 70 km) with no major structural traps. Plume-scale, dynamic injection simulations show high potential injection rates of over 10 million tonnes supercritical CO2 per annum. After 1000 years, the model predicts maximum plume migration of 30 km from the simulated injection wells. A CO2 storage resource potential of over 15,000 million tonnes was estimated for the reservoirs over the entire Petrel Sub-basin using a methodology suitable for MAS plays.
The highly suitable reservoirs are located less than 300 km from major local CO2 emission sources. This study shows that the Bonaparte Basin in northern Australia is potentially a highly prospective location for carbon capture and storage projects in Australia, and possibly for the broader region.
Quartz Technology Allows for Wider Downhole Pressure Testing Range
Authors: Dennis J. R. , Zeller V. P. 
Published: October 2015

ABSTRACT
A quartz thickness shear mode transducer for utilization in a borehole environment is presented. The pressure sensor is a direct conversion device which utilizes a non-cylindrical shell to convert and transmit forces to the quartz crystal resonator. A brief conceptual description of the transducer is given. Both laboratory and field examples are presented which illustrate the exceptional performance of the quartz thickness shear mode transducer.
Attracting Applicants for In-House and Outsourced Internal Audit Positions: Views from External Auditors
Authors: Bartlett Geoffrey D. , Kremin Joleen , Saunders K. Kelli , Wood David A. 
Published: October 2015

SYNOPSIS
While the internal audit function (IAF) plays a critical role in organizations, it faces challenges in finding sufficient numbers of high-quality job applicants to fill its ranks. The results of two experiments suggest that practicing external auditors are twice as likely to apply for positions that are labeled as accounting positions rather than either in-house or outsourced internal audit positions. The results also suggest that external auditors have negative perceptions of the profession and work environment of internal auditors—especially in-house internal auditors relative to outsourced internal auditors—and are more likely to recommend that mediocre rather than top students apply to work in internal auditing. We also provide survey results from experienced external auditors about aspects of internal auditing that may be improved to make it a more attractive career option. Taken together, the results suggest internal auditing faces significant hiring challenges, but also offer ways to mitigate these challenges.
Conflict Minerals Disclosures: Reporting Requirements and Implications for Auditing
Authors: Sankara Jomo , Lindberg Deborah L. , Razaki Khalid A. 
Published: October 2015

SUMMARY
Section 1502 of the Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010 (Dodd-Frank Act) created a reporting requirement for publicly traded companies that manufacture products using “conflict minerals” from the Democratic Republic of the Congo (DRC) or adjoining countries. Under certain circumstances, companies must file a Conflict Minerals Report (CMR) in addition to a Specialized Disclosure Report (Form SD). Companies that claim their products are free of conflict minerals from the DRC must have an audit of their CMR. We investigate the extent to which companies have complied with the new disclosure requirements as well as the current and future auditing implications.
Comments by the Auditing Standards Committee of the Auditing Section of the American Accounting Association on PCAOB Release No. 2015-004, Supplemental Request for Comment: Rules to Require Disclosure of Certain Audit Participants on a New PCAOB Form
Authors: Doxey Marcus M. , Geiger Marshall A. , Hackenbrack Karl E. , Stein Sarah E. 
Published: October 2015

SUMMARY
On June 30, 2015 the Public Company Accounting Oversight Board (PCAOB) issued a supplemental request for comment on its 2013 reproposal to require auditors to disclose in the auditor's report the name of the engagement partner and information about certain other participants in the audit. The supplemental request solicited public comments on an alternative to disclosure of this information in the auditor's report, namely that audit firms report (1) the name of the engagement partner, and (2) the names, locations, and extent of participation of other audit participants in a new form (Form AP) to be filed with the PCAOB within 30 days of the date the auditor's report is first included in a document filed with the SEC. The comment period ended on August 31, 2015. This commentary summarizes the participating committee members' views on the alternatives presented in the supplemental request for comment.
Data Availability: The exposure drafts of the proposed and reproposed rules, the supplemental request for comment, and related information are available at: http://pcaobus.org/Rules/Rulemaking/Pages/Docket029.aspx