bluuebunny/crossref_metadata_2025_split huggingface dataset:
Systems Of Action - A Blue Print For Real-time Decision Support Systems
Authors: Wesenberg Harald , Landre Einar 
Published: September 2015

Abstract
Capability stacks have proven to be a useful tool for organizing and reasoning about business capabilities. At Statoil we have used it for our Integrated Operations initiatives, as well as for other initiatives such as Integrated Environmental Monitoring. In this paper we introduce and illustrate the concept of capabilities stacks, and describe how the concepts of such a capability stack would be implemented using micro-services and autonomous multi-agent systems supporting a real-time decision support system. The introduction of multi-agents changes the system from a “system of record” (where a human operator is firmly in control and the system provides information for the human operator to make decisions) to a “system of action” (where multi-agents analyze and take action based on available information, and where a human operator has less influence (but remains firmly in control) over the system actions.
The introduction of micro-services and multi-agents provides numerous benefits from a systems engineering perspective. Micro-services allow for the isolation of capabilities in easily definable contexts that interacts with their environment through a set of well-defined interfaces, while multi-agents allow for simplified reasoning around capabilities through the goals and rules of the agents without necessarily knowing all of the implementation details. In turn, this allows for a useful discussion around capabilities, and by stacking these capabilities according to a few design principles we are better able to understand and reason about the total system capabilities within a reasonable timeframe and with reasonable amount of analysis resources.
A Three-Dimensional Thermal Model for Hydraulic Fracturing
Authors: Amini Kaveh , Soliman Mohamed Y. , House Waylon V. 
Published: September 2015

Abstract
Distributed Temperature Sensing (DTS) can provide the wellbore temperature profile during the hydraulic fracturing treatment. This temperature profile is a complex function of many parameters including leakoff coefficient, thermal conductivities of the rock and the injected fluid, minimum stress, porosity, etc. Because of these complexities analytical solutions are not capable of adequately determining the effect of these various parameters on the temperature profile. Moreover, these parameters may vary from one layer to another. Therefore, a three-dimensional temperature model is needed to estimate the fracture parameters by matching the wellbore temperature profile with simulation results.
A three-dimensional temperature model was developed to determine the temperature profile in and around the fracture based on a pseudo three-dimensional (P3D) fracture propagation model. The propagation model, the wellbore thermal model, and the fracture thermal model were solved simultaneously to consider the effect of temperature and pressure on various parameters, such as specific volume. Moreover, the results of the fracture propagation simulation of five cases were compared with the results of full 3D simulators, obtained from literature.
The fracture half-length, fluid efficiency and the net pressure at the entrance of the fracture simulated by this model were in good agreement with the results of full 3D simulation. The minifrac propagation, closure and its temperature were also simulated by this model. The pressure decline curve was predicted by simulator while the effect of temperature and pressure on other variables, such as fracturing fluid density and viscosity, was considered. Additionally, it was observed that the location of optical fiber cable was very important in DTS temperature measurement. Accordingly, a method is provided to consider the effect of the distance of the fiber optics cable from the fracture.
The development of this hydraulic fracturing 3D thermal model is another step for the interpretation of the wellbore thermal profile, measured by the DTS technology during hydraulic fracturing treatment. This model is also capable of being used for more accurate hydraulic fracturing design and analysis.
Nanotechnology Improves Wellbore Strengthening and Minimizes Differential Sticking Problems in Highly Depleted Formation
Authors: Al-Baghli Waleed , Saradhi Vijay , Anas Muhammed , Alherz Ahmad , Rajagopalan Arun , Tobeh Samir , Khatib Faiz , Jadhav Prakash , Yadav Prahlad 
Published: September 2015

Abstract
It is a challenge to drill in highly deviated or horizontal holes across the highly depleted formations. Wellbore instability, differential sticking and mud loss are frequently encountered problems while drilling a depleted reservoir in deep HTHP wells in Kuwait. Long-term production caused formation pressures to be highly depleted, and drilling became more challenging with considerable non-productive time. Therefore, it is necessary to identify a fluid’s solution when other options with casing zone isolation are not viable. Traditionally, oil-based mud (OBM) was used while drilling these formations with limited success.
A customized fluid system was designed to overcome the issue of high overburden pressure in depleted formations targeting effective bridging, minimizing pore pressure transmission and strengthening the wellbore. A nano-size deformable synthetic polymer, along with sized calcium carbonate and graphite, was identified to effectively plug the pore throats and minimized the fluid invasion, which was confirmed by particle plugging tests.
A well section was identified to comingle the highly depleted and pressurized formations. This was the first attempt on a high-angle well with deep drilling operations in Kuwait and was performed to facilitate the successful drilling of the reservoir. Traditional OBM was converted to a customized fluid system using a nano-size polymer and sized bridging additives based on proprietary software selection and series of laboratory tests. Drilling, coring and logging were successfully performed for the first time in the commingle section without incident. There was no wellbore instability or differential sticking tendencies, less torque and drag, as well as enhanced wellbore cleaning in the high-angle sections.
This paper also presents the some of the successful applications of the nano-size deformable polymer in OBM to drill highly depleted formations in HTHP wells managing upto 3500 psi overbalalnceacross highly permeable formations.
Numerical Analysis for Promoting Uniform Development of Simultaneous Multiple Fracture Propagation in Horizontal Wells
Authors: Wu Kan , Olson Jon , Balhoff Matthew T. , Yu Wei 
Published: September 2015

Abstract
Multi-stage hydraulic fracturing together with horizontal drilling plays an important role in the economic development of unconventional reservoirs. However, according to field analysis of stimulation effectiveness, only a small percentage of perforation clusters contribute to most of the well production. One reason for this low effectiveness is that multiple fractures do not take the same amount of fluid and proppant due to fracture interaction (i.e., stress shadow effects). Unfortunately, how best to minimize the negative effects of stress shadowing is still poorly understood in the petroleum industry. In this paper, we analyzed this problem in order to promote more uniform fracture growth using our complex hydraulic fracture development model.
We employed our fracture propagation model that couples rock deformation and fluid flow in the fracture and horizontal wellbore. Partitioning of flow rate between multiple fractures was calculated by analogizing to the electric circuit network. Fracture development is dominated by flow rate distribution, which is controlled by flow resistance within the fractures. For simultaneous multiple fracture propagation, non-uniform flow rate distribution is induced because stress shadow effects exert additional flow resistance on the interior fractures. To balance the extra resistance introduced by the effects, we investigated two adjustment approaches to promote uniform fracture development. The first approach was to adjust perforation number or diameter to increase flow resistance entering the exterior fractures. The second was to mitigate stress shadow effects through managing non-uniform fracture spacing. We found that decreasing perforation diameter or numbers of the exterior fractures can divert fluid into the interior fractures and promote even fracture growth. Stress shadow effects can be mitigated by moving the two interior fractures away from each other and toward the exterior fractures. The key mechanism is to maintain even flow resistance within each fracture and facilitate fractures to obtain the same amount of injection fluid. Furthermore, flow resistance is affected by near-wellbore fracture tortuosity, natural fractures, and stress heterogeneity in the reservoirs. These factors might also be effectively controlled by adding extra flow resistance to pass perforations, provided that this extra resistance is larger than the extra resistance introduced by the factors.
This work analyzes the problem of uneven development of multiple fractures along the horizontal wellbore and provides new insights into how to control simultaneous multiple fracture propagation. It offers potential approaches for engineers to apply in the field to optimize hydraulic fracturing treatment design and thereby maximize well production cost-effectively.
Structuring an Integrative Approach for Field Development Planning Using Artificial Intelligence and its Application to an Offshore Oilfield
Authors: Ketineni Sarath Pavan , Ertekin Turgay , Anbarci Kemal , Sneed Tom 
Published: September 2015

Abstract
In early stages of reservoir depletion, it is often a challenging task to accurately determine reservoir properties that are representative of the actual field. Due to different scales of data obtained from various sources like seismic data, well logs, cores, and production data, there is a lot of uncertainty in solving the inverse problem of estimating formation rock and fluid properties from the field data. Hard-computing protocols like reservoir simulation are time and labor intensive. The objective of the current study is to develop a reservoir characterization tool using a novel approach of correlating seismic attributes with well logs and production data using artificial intelligence approach. The tool will enable construction of spatial oil maps at different times revealing sweet spots and aid in optimized field development planning.
A workflow is developed for devising a comprehensive reservoir characterization tool based on artificial expert systems. A case study of an offshore deep-water asset is used in demonstrating the tenets of the workflow. The reservoir under consideration is highly heterogeneous in terms of property distribution and is believed to be highly channelized. The ANN based tool assists in identifying sweet spots by predicting optimal well location/completion parameters and production profiles.
The multilayer feedforward back-propagation based neural network tool developed is able to capture the correlations that exist amongst seismic data, well logs, completion data, and production data. Well logs are correlated to seismic attributes and geometric location of wells with an average testing (blind test) error of less than 20%. Having correlated seismic data with well logs, synthetic well logs are generated for the entire area of seismic coverage. Synthetic well logs combined with seismic data are able to correlate well with the production within 21% error. The tool developed enables users to predict entire well log suites for even a directional well of user defined configuration through a graphic user interface in a short period of time (typically less than a minute).
This methodology uses a unique way of computing seismic attributes following a horizontal well path and correlating them with the suite of well logs. Incorporation of interference effect from neighboring producers and injectors, schedule of production and functional links based on geographic location has made the production performance module robust and reliable. The workflow enables generation of oil production forecast maps through production performance network. NPV (net present value) calculations integrated with production forecasts is used in identifying the potential infill well locations. The results discussed in the paper showcase the robust nature of the methodology.
Advanced Data-Driven Performance Analysis For Mature Waterfloods
Authors: Mijnarends Runo , Frolov Andrey , Grishko Fedor , Kryanev Svyatoslav , Mikhaylenko Egor , Nizamutdinov Eduard , Plokhotnichenko Oleg , Irina Surovets , Ulyanov Egor , Volokitin Yakov , Gladkov Andrey , Belyanushkina Maria , Lvov Anton 
Published: September 2015

Abstract
We present a novel, data-driven approach to integrated well/reservoir performance analysis and opportunity identification for mid- to late-life pattern waterfloods.
The Salym group of oilfields is located onshore in Western Siberia, Russia's prime oil producing province, and is operated by Salym Petroleum Development (SPD), a 50-50 joint venture between Shell and Gazprom Neft. The main productive formation, comprising strongly layered, deltaic/fluviatile sandstones, has been developed as a pattern waterflood, with over 950 deviated wells drilled since 2004. Overall watercut is currently around 82% and with oil production declining at 6-7% year on year, waterflood management is an absolute strategic priority.
The operator has responded to this challenge by investing heavily in waterflood management and performance evaluation. Particularly, a dedicated effort was made to develop the company's enterprise information architecture and create a purpose-built online waterflood management tool (WMT). All Salym geological, completion, production and well status data is automatically quality-checked, stored and updated in an integrated waterflood database and made accessible through the WMT. The WMT provides a wide range of functionality for data visualization, performance diagnostics and analysis. Furthermore, it is coupled to a full-field surveillance simulation model, which auto-updates with new oilfield data as it becomes available and outputs streamlines, well allocation factors, maps of remaining oil distribution and pattern- and block-level calculated properties.
These technologies have enabled the development and implementation of a structured methodology for waterflood performance evaluation that involves systematic assessment of blocks of 20-50 wells in the form of an Annual Field Review (AFR) followed by a series of deep-dive Integrated Block Reviews (IBRs). During the AFR, each block is assessed against a set of KPIs and scored and prioritised in terms of its health status and projected recovery shortfall. Based on this prioritisation, blocks are scheduled for review in an IBR during the course of the year. The IBRs focus on individual wells, patterns and reservoirs and during the reviews concrete well, reservoir and facilities management (WRFM) opportunities are identified to address performance gaps and sweep or accelerate remaining oil. These opportunities are captured in an online opportunity register coupled to an online database for workover strategy preparation.
The framework of technologies and processes presented in this paper was instrumental in planning and executing over 260 WRFM activities (not including simple pump change-outs) across the Salym fields in 2014, delivering in excess of 3.2 Mln bbls of in-year oil production.
Acoustic Signature of Flow From a Fractured Wellbore
Authors: Chen K. , Zhu D. , Hill A. D. 
Published: September 2015

Abstract
Distributed acoustic sensing (DAS) technology is emerging in the area of hydraulic fracture monitoring and diagnosis. The number of applications using DAS technology has been growing significantly from determining flow distribution to detecting multiphase flow. Some of the current DAS technology in the hydraulic fracture diagnosis area utilizes sound intensity on the spectrogram plot of the acoustic measurements to qualitatively analyze fracture initiation.
In this paper, we present the results of our simulated fracture, perforation tunnel, and wellbore system experiments measured by a distributed hydrophone array in both the time and frequency domain. The experiments were conducted on a wellbore with two fracture cells. The wellbore can be either horizontal or vertical. The customized fracture cells with long and thin geometry were connected through a perforation tunnel to a 5-inch ID wellbore. In the horizontal wellbore setup, fluid was injected through the fracture cells and perforation tunnels to the wellbore. The experiments used hydrophone and microphone array to measure the acoustic signals from each fracture. Relative locations of the hydrophones to the fractures and the rate difference from the two fractures are the main parameters examined during the experiments. The measured acoustic data were analyzed using DSP techniques to characterize the location and rate differences. We first studied how the fracture and perforation tunnel alone affect the acoustic signature of the flow from the fracture to the wellbore; this study allows extraction of individual fracture and perforation related information from the overall measured DAS data from the combined system. We then analyzed how multiple perforation tunnels and different flow distributions changed the acoustic frequency spectrum. Additional parameters affecting acoustic behavior were investigated including single phase liquid, multiphase fluid, and liquid column. The digital signal processing (DSP) algorithm is explained in the paper. A correlation based on experimental observation was developed to quantitatively estimate the flow rate and flow distribution of multiple perforation tunnels from acoustic signals measured in the wellbore.
Well Integrity Management: Forecasting CO2 Cavity Corrosion on Tubing of Gas Wells
Authors: Alsalman Malik , Nasizadeh Zoha , Hosseini Masoud M. , Samuel Robello 
Published: September 2015

Abstract
Well casings and tubing strings are subjected to severe corrosion because of their exposure to severe environments provided by corrosive fluids during production. The problem can be more challenging when dealing with deep formations at high temperature and pressure. The tubular string exposed to corrosion suffers from strong degradation that can lead to tubing burst and collapse. It is highly desirable to predict the threshold pressure for degraded tubing strength, and design the tubing strings with consideration of these corrosion effects. The objective here is to forecast the corrosion effect on tubing-strength degradation throughout the entire life of the well.
The worst-case corrosion caused by CO2 in gas wells has been considered. This type of corrosion causes pitting cavities, which reduces the tubing strength over time. The effect of possible cavity depth and diameter on the stress-concentration factor is considered as well. The pressure profile of the production has been coupled with the phase envelope of the fluid along the well to find the region of maximum CO2 condensation. Then the Dewaard et al. model of CO2 corrosion rate is used to find the growth of corrosion cavity at the depth of maximum CO2 condensation. Finally, the cavity size is applied to the stress concentration factor model to find the degradation of the steel strength during well production at this depth.
What makes this work unique is that it uses four different fields related to petroleum engineering, which are production, phase equilibrium, corrosion, and steel strength, to build a corrosion model that can be applied to various types of steel to predict the collapsing of the tubing during the production. Therefore, several collapsing or leaking problems can be prevented that consume both money and time. Also, this study can be expanded to include other corrosive factors and components, such as the pH of the fluids and H2S, which is a very corrosive component.
Successful Squeezing Operation of Magnesium Based Ultrafine Cement Through Wire Wrapped Screen With Mesh Size of 20/40
Authors: Karim Nurul Aiman , Ellis Todd B , Maluan Lilihani 
Published: September 2015

Abstract
Utilization of chemical treatment to isolate or shut off zone is not uncommon in this industry. Cement will normally be chosen as candidate to perform the job as it is more permanent and more economically effective. With recent advanced technologies, cement particles are now designed to be in smaller particles yet still be able to develop sufficient amount of compressive strength for effective zonal isolation and hydraulic seal. Magnesium based Ultrafine Cement System was chosen as chemical candidate to be used in Sarawak West Oil Field. The primary purpose of using this cement system is to penetrate through Wire Wrapped Screen with Mesh Size of 20/40 in the completion. The utilization of Ultrafine Cement in the operation was incorporated with Calcium Carbonate and Cement G slurries. Calcium Carbonate will act as the suspension fluid while Cement G slurry will be pumped to fill up the inside volume of Wire Wrapped Screen after Ultrafine Cement being pumped to occupy the outside volume of Wire Wrapped Screen. Compatibility test between Ultrafine Cement and the two slurries had been tested in the laboratory and it was reported that there was no significant change of viscosity value when they are mixed together. Application of Ultrafine Cement in Sarawak West Oil Field indicated that all Ultrafine Cement pumped during the operation was managed to pass through the 20/40 Mesh Size. Tubing Clearance Check (TCC) by Slickline showed high held up depth (HUD) but Coiled Tubing was used to run in hole to confirm on the HUD depth. It was reported that there was no significant weight loss when Coiled Tubing passing through Slickline HUD. Coiled Tubing stopped run in hole at Top of Calcium Carbonate to avoid disturbing the suspension fluid. Based on this situation, it is also known that there was no presence of Ultrafine Cement settle on top of Calcium Carbonate at all due to its efficiency in penetrating the Wire Wrapped Screen.