bluuebunny/crossref_metadata_2025_split huggingface dataset:
Applicability Criteria for Subsea Developments: A Study on the HSE Aspects, Technical Limits, Commercial Constraints, and Other Non-Technical Factors to be Discussed while Framing and Sanctioning a Subsea Project
Authors: Beltrami Francesco 
Published: October 2018

Abstract
The persistence of the current downturn of the subsea industry offers the opportunity to rethink the reasons of the success of subsea and deepwater projects over the past two decades to (a) identify where and how subsea technologies can be effectively used to create value for an operator, and (b) which are the subsea applicability limits, either real or perceived, that may suggest opting for a different field development concept.
This paper discusses the definition and use of the applicability criteria for subsea developments. Further to a brief methodology note, these criteria are then used to map, in a qualitative way, different situations where a project may benefit from the adoption of subsea technologies.
HSE aspects, technical limits to the required technologies, commercial constraints, profitability during field life, effectiveness of hydrocarbons recovery and other non-technical factors (from human error to geopolitics) are illustrated and arranged into a logical, clear frame to map the proposed applicability ranges for subsea developments.
The applicability maps are then employed to briefly discuss some significant aspects of the booming success of the subsea industry from its first ‘golden age’ (1999-2014) and also a few issues and challenges that deserve some attention while preparing for the next subsea and deepwater ‘boom’.
Implementation of a Fully Automated Real-Time Torque and Drag Model for Improving Drilling Performance: Case Study
Authors: Shahri Mojtaba , Wilson Timothy , Thetford Taylor , Nelson Brian , Behounek Michael , Ambrus Adrian , D’Angelo John , Ashok Pradeepkumar 
Published: October 2018

Abstract
The drilling industry has made significant progress on physics-based torque and drag (T&D) models that can run either offline (pre-job or post-job) or in real-time. Despite its numerous benefits, real-time T&D analysis is not prevalent since it requires merging real-time and contextual data of dissimilar frequency and quality, along with repeated calibration whose results are not easily accessible to the user. Our goal is to implement a rig-based T&D advisory system which overcomes these obstacles.
The first step towards real-time T&D analysis is a reliable data acquisition and processing system at the rig site. This includes the ability to receive and process data of different frequency and merge it with contextual data. Once this was accomplished, the system was implemented on more than 20 rigs in North America. We then adopted a soft-string T&D model to be used for various purposes including the automatic detection of overpull/underpull events and the depths where these occur, open-hole and casing friction factor determination, sensor calibration and real-time broomstick plotting and field data comparison for subsequent casing run design.
In this paper, we demonstrate the field and office application and usage of a real-time T&D model. The system on which the model is run must be able to merge both real-time (hook load, torque, rig state, etc.) and contextual (BHA composition and specifications, wellbore design and trajectory, mud weight, etc.) data. Given the developed infrastructure, the drilling engineers have access to automated model calibration in real-time which enhance the reliability and repeatability of results and also contribute to time/cost savings. Using the embedded rig state identification engine, different real-time data points can be classified (e.g., slack-off, pick-up and rotating off-bottom) and used in T&D calibration. In addition to traditional broomstick plots, the algorithm uses probabilistic data analytics approaches to identify troublesome zones (e.g., overpull/underpull locations). In a fully automated manner, the platform generates predictions based on calibrated friction factors to enhance subsequent casing run as well. The outputs are used in both field and office in a variety of ways to improve drilling performance and safety.
Using the developed platform, we automated the process of T&D analysis and reduced/eliminated the time/cost required to run physical models offline. Using data from multiple BHA runs and one casing run from an exemplary well in North America, we were able to demonstrate the benefits of the automated real-time application in comparison to the traditional offline use of torque and drag analysis.
Review of Professional Engineering in Petroleum Engineering
Authors: Kinney Lance , Norwood Catherine 
Published: October 2018

Abstract
Many individuals who practice in the field of oil and gas production, transportation, and refining perform engineering tasks and activities but do not become licensed as Professional Engineers for a variety of reasons, such as statutory exemptions, corporate policies, or lack of understanding of the value of professional practice in an area with a high potential impact on health and safety. This paper uses information from state boards of licensure, national organizations related to petroleum engineering, and case studies to address these misunderstandings related to licensure. The value of licensure as a Professional Engineer in the area of petroleum engineering is summarized, including statutory requirements and exemptions to practice in various U.S. states. The licensure process for Professional Engineers is explained, including education, experience, and examination requirements. Professional practice and ethical standards are discussed. While some jurisdictions do not specifically require licensure to practice in the area petroleum engineering, there are a number of advantages for individual practitioners to become licensed as a Professional Engineer. Examples are provided to explain how professional engineering licensure can protect the health, safety, and welfare of the public, as well as benefit the individual practitioner and industry as a whole.
Developing a New Technique for Calculating Accurate Water Saturations from Well Logs in Source Rocks
Authors: Hillier Ryan , Vosburgh Eric , Warrington Daniel , Ibrahim Mazher 
Published: October 2018

Abstract
Determining log-based water saturation using Archie's (1942) equation, or any derivative shaly sand method, requires correct inputs to produce valid results. In resource plays, the rock matrix is composed of water wet and oil wet constituents, therefore, correct values of Archie's cementation factor (m) and saturation exponent (n) are critical. In practice, it is pragmatic to use the Pickett plot (Pickett, 1973) to set connate water resistivity (Rw) and Archie's ‘m’. However, it is difficult, if not impossible, to derive Archie's ‘n’ parameter without additional information. Research combining core and log data shows evidence of a positive correlation between Archie's saturation exponent and the total organic content (TOC) in a given unit volume. Using this relationship, Archie's equation may be used to define a variable ‘n’. It is hypothesized that ‘n’ increases with increasing TOC volume as a result of an interruption of electrical pathways that resistivity tools exploit. This disruption results in an increase in the apparent value of ‘n’ required to compute correct water saturations. Due to the apparent excess resistivity in organic-rich rocks, an increase in ‘n’ values or kerogen corrected resistivity is needed to produce a fit to core-derived water saturations. This article will demonstrate the methodology used to derive a variable ‘n’ parameter and kerogen corrected resistivity in an organic-rich interval.
Who Are the Innovators in the Upstream Oil & Gas Industry? Insights From the 2017 SPE Global Innovation Survey
Authors: Perrons Robert K. , Burgers Henri , Newton Cameron 
Published: October 2018

Abstract
Technology and innovation are playing increasingly important roles in the success or failure of tomorrow's upstream oil & gas firms. Building upon the successful first SPE Innovation Survey in 2012 which looked at innovation at the business unit level, a second survey was carried out in 2017 to examine these processes again within the industry, but this time from the point of view individual people. This paper uses data from the 2017 survey to find out who the "explorers" are within the oil & gas sector that seem to be hardwired to deliver tomorrow's bolder technologies, and who the "exploiters" are that, for whatever reason, find it more difficult to bring about significant technological change within the industry. We found several potentially useful patterns in the data. First, people with graduate degrees are noticeably more likely to engage in exploration kinds of behaviors than people who do not. Second, respondents who spent their formative years before the age of 18 in Norway, Russia, or Indonesia report having more exploration kinds of activity than most others. Third, people currently working in Brazil, China, Malaysia, Nigeria, and Venezuala all reported lower levels of exploration-like behavior than their counterparts elsewhere. And expatriate employees seem not to be any more predisposed to exploration activities than non-expatriates. The paper concludes with a discussion about the 2017 survey's methodological shortcomings and, based on those, recommendations for future investigations in this area.
Integrated Well Integrity Cement Evaluation Technique for Shallow Gas Flow Cementing in Eagle Ford Field
Authors: Dooply Mohammed , DeBruijn Gunnar , Martinez James 
Published: October 2018

Abstract
Cement job design has historically been a static process largely independent of the other processes in the drilling and completion phases. The success or failure of achieving zonal isolation, which is the main objective of cementing, is usually attributed to the cement placement result without analyzing in details various factors such as drilling parameters, borehole shape, drilling fluid properties, casing designs, formation properties (temperature and pressure profiles), and even cement evaluation methods including post-cement placement activities that could contribute to the end result of achieving zonal isolation objectives for long-term well integrity on an oil and gas well.
A unique workflow is developed by incorporating data from different stages of the well construction process (drilling, cementing and cement evaluation) to optimize the cement job design and placement evaluation for critical and challenging wells. By integrating real-time or near real-time data from drilling and cementing phases, the unique workflow rapidly identifies critical information that can prevent poor cement placement, which allows operators to make timely decision to achieve well integrity and safe working environment.
An integration of drilling and openhole information, cement slurry design and placement/mud removal result, and cement evaluation log evaluation is required to better understand zonal isolation and well integrity, particularly for wells with shallow hazards. This case study explains an integrated workflow implemented during cement placement design and evaluation on surface casing cementing job after failure of a conventional cement barrier placement in the Eagle Ford field in south Texas.
Estimating Hydraulic Fracture Geometry by Analyzing the Pressure Interference Between Fractured Horizontal Wells
Authors: Seth Puneet , Manchanda Ripudaman , Kumar Ashish , Sharma Mukul 
Published: October 2018

Abstract
Pressure interference measurements in fractured horizontal wells have been used to characterize hydraulic fractures (Kampfer and Dawson, 2016; Roussel and Agrawal, 2017). Past work has modeled this interference using static reservoir gridblocks as a proxy for hydraulic fractures. In this paper, we show that to accurately interpret the pressure response observed in a fractured monitor well, one needs to explicitly model the fractures and their propagation as a compliant discontinuity in the reservoir.
A fully-coupled 3-D geomechanical reservoir model which models fractures explicitly as open and compliant channels has been developed to simulate pressure interference between hydraulic fractures in a multi-well pad. Using this model, we simulate dynamic fracture propagation at the treatment well while monitoring pressure at the monitor well. The pressure response inside the monitor well fracture is calculated accurately by explicitly modeling the monitor well fracture as a compliant discontinuity in the reservoir rock. We study the impact of mechanical stress interference between the fractures. The model is then used to simulate and analyze the treatment pressure response observed in a pair of wells in the Permian Basin.
Simulation results indicate that hydraulic fracture propagation towards the monitor well results in changes in stress on the monitor fracture. Closure and opening of the monitor fracture is manifested directly as an increase/decrease in pressure in the monitor well fracture. We show that this pressure change in the monitor well is observed primarily because of the elastic effect of mechanically squeezing the monitor fracture by the dynamically propagating hydraulic fracture (not by direct hydraulic communication). As such it is essential to model the compliance of the fractures as has been done in this study. This monitor well pressure response is systematically analyzed to estimate fracture geometry for field data obtained from a Permian Basin well pad.
Our representation of the propagating hydraulic fracture and the monitoring well fracture as compliant discontinuities in the reservoir is for the first time shown to be essential to capture the pressure response observed in the field. Previous models have simplified the problem by representing the fracture as static reservoir grid-blocks, and such models are clearly inadequate. Our model captures the impact of a propagating hydraulic fracture on the pressure response observed in a fractured monitor well much more accurately. Such pressure interference analysis can provide operators with a semi-quantitative estimate of hydraulic fracture geometry, relatively inexpensively.
Grid Cluster in the Office: High-Performance Computing for Reservoir Management
Authors: Yaubatyrov Ramil , Babin Vladimir , Liya Akmadieva 
Published: October 2018

Abstract
Optimal reservoir management usually requires evaluation of a large number of various development scenarios. This applies to a choice of well placement and settings configuration, waterflooding strategy and history matching process. Reservoir models are commonly used to obtain field production forecast depending on the development plan. Generally, a specialized external high-performance computational environment is used to accomplish the aforementioned multivariate calculations, while personal workstations stay idle most of the time. We propose an alternative way of organizing HPC environment using available computational resources. The method is based on integration of several personal workstations into a so-called grid cluster using local network, which allows managing the whole system from any connected node. Each computational node is provided with a flexible timetable to ensure that distributed calculations do not interfere with daily work. The solution does not require additional capital investments and is easy to implement in the office. Although initially designed for hydrodynamic simulations, the system can be used for any time-consuming multivariate task.
Proposed method has been applied to several optimization cases of real fields. Grid cluster consisting of fifty nodes with estimated peak performance of 60 TFLOPs was used to find optimal development plan for a field in Western Siberia, allowing to reduce computational time from several months to one weekend. The system prooved linear speedup depending on the number of involved workstations along with stability under conditions when each node may connect or disconnect at any time.
Proven Experience in Construction of Multilateral Wells Using TAML 1 Technology in Novoportovskoye Field
Authors: Pilnik Sergey , Dubrovin Andrey , Zimoglyad Mikhail , Bulatov Fuat , Burkov Fedor , Abaltusov Nikolay 
Published: October 2018

Abstract
The key opportunity of Novoportovskoye Field is hydrocarbon reserves, which remain undeveloped. In this field, significant oil reserves directly underlie massive gas caps. Economic efficiency in such geological conditions is based on the use of new technologies for the maximum extension of field infrastructure loading.
This paper reviews prerequisites and cases of multilateral well drilling technologies as an efficient EOR method at Novoportovskoye Field. The paper summarizes the results of drilling of nine multilateral wells.
The strategy of multilateral well completion at Novoportovskoye Field increased the level of complexity defined by technology advancement for multi-laterals (TAML). First, a multilateral well with an openhole lateral was drilled. This openhole section collapsed when the well was brought into production at the target drawdown. Therefore, the second stage was to construct a multilateral well with cased main bore and lateral using TAML-1 technology.
A version of TAML-1 technology developed by a Russian manufacturer was adapted and implemented at this stage.
Several sidetracking methods were tested to reduce the rig time and multilateral well construction costs. Application of rotary steerable systems (RSS) for sidetracking instead of conventional rotary assemblies and downhole motors enabled to reduce the average sidetracking time from 70 to 30 hours. The record time of sidetracking using RSS was 16 hours.
The history of Novoportovskoye Field development demonstrates a continuous trend towards increasing horizontal section lengths from 1,000 to 1,500 and 2,000 meters. The cumulative multilateral well drilling experience enabled construction of a well with four laterals with a total length of horizontal sections of 4,411 meters. It was the first well with four laterals in Russia built according to TAML-1 technology.
As compared to conventional horizontal wells, the highest initial incremental oil rates were registered in multilateral wells drilled in the Jurassic Yu2-6 interval and the Cretaceous NP2-3 interval of the Novoportovskaya Formation. Considering that the share of the Yu2-6 interval in the oil reserves of Novoportovskoye Field is 46% and the share of the NP2-3 interval is 17%, the operator decided to increase the share of multilateral wells to develop these intervals.
The project objective for 2018 - 2020 is to increase the number of cased holes, to separate laterals to the maximum possible distance, and to improve the completion level to TAML-4.
Improving the Understanding, Application and Reliability of the Perforate, Wash and Cement Technique through the Use of Cement Bond Logs, Tool Enhancements and Barrier Verification via Annular Pressure Monitoring
Authors: Lucas Alexander , Stokkeland Thore Andre , Jackson David , Ingram Scott 
Published: October 2018

Abstract
The Perforate, Wash and Cement technique has been widely applied to remediation of annular cement in recent years. Since 2012, extensive experience in the different technologies currently available on the market has been obtained across ten fields in the Danish and UK sectors of the North Sea and the data obtained has been used to attempt to better understand the effective operational window for the technique, and also further enhance reliability and tool robustness.
The run data obtained from several wells has been calibrated against cement bond logging (CBL) responses so that the degree of annular bonding as inferred from the logs may be expressed in terms of the degree to which hydraulic communication or circulation is permitted via perforations and along the annulus. This in turn helps clearer decision criteria to be defined prior to execution that aids in the selection of the most appropriate method for remediating the cement, since Perforate, Wash and Cement may not be the most suitable technique in every case.
Given the criticality of cement remediation to the long-term success of zonal isolation, it is important to demonstrate that effective hydraulic communication with the annulus has been established during the washing phase to ensure that the zonal isolation medium (cement) can be effectively placed and the hydraulic seal re-established, resulting in successful remediation.
Post-execution verification of the effectiveness of remediation is typically performed via Cement Bond Logging. However, this may not always be a definitive verification step since Cement Bond Logging interpretation does have its limitations (both physical and interpretative), and hence annuli have occasionally been known to develop Sustained Casing Pressure even shortly after positive log interpretations following well-executed cementations.
This paper therefore further demonstrates how Sustained Casing Pressure monitoring can be used as a further criterion to verify the integrity of the remediated annulus and hence conclusively demonstrate whether the washing and later cementing of the annulus has been effectively performed. This in turn is used as definitive confirmation that zonal isolation has been performed within the operating limits of the tool and hence qualify Perforate, Wash and Cement as a robust and viable remedial method.
An Equation of State to Model Microemulsion Phase Behavior in Presence of Co-Solvents Using Average Solubilization Theory
Authors: Ghosh Soumyadeep , Chawathe Adwait , Thach Sophany , Linnemeyer Harold C. , Tao Emily B. , Dwarakanath Varadarajan , Ambastha Anil , Arachchilage Gayani Pinnawala 
Published: October 2018

Abstract
Co-solvents are used with surfactants in modern chemical enhanced oil recovery (CEOR) formulations to avoid formation of viscous microemulsion phases (and reduce costs) in porous media. Modeling the effect of co-solvents on phase behavior is critical to CEOR reservoir simulations. The state-of-the-art is to use HLD (Hydrophilic Lipophilic Difference) with a modified form of NAC (Net Average Curvature) as an Equation of State (EoS) to model microemulsion phase behavior. In this paper, we use an alternative EoS flash algorithm and couple it with an alcohol partitioning model to predict physical phase behavior.
In this paper, we show that the net curvature equation in NAC is not valid for overall compositions away from typical experimental conditions, specifically in Type I and II systems. Alternatively, we use experimental evidence to correlate the harmonic average of oil and brine solubilization ratios to HLD. We use the average solubilization ratio equation with boundary conditions that allow for microemulsion phase type regions to be well defined, thus making the flash calculations robust. To model the co-solvent effect, we couple the newly developed average solubilization theory (AST) based EoS with the Prouvost-Pope-Rouse model to capture co-solvent partitioning across oil, brine and microemulsion phases. The resulting AST theory allows for a HLD based EoS to predict physical two-phase regions with no discontinuity in phase behavior thereby making it a more robust alternative to HLD-NAC. We used 80 phase behavior experiments over a wide range of hydrocarbons and temperatures to validate our approach. The coefficient of determination between the actual experimental data and the predicted model output was found to be above 0.9.