bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Efficacy of Market-Based Emission Control Systems: A System Dynamics Approach
Authors: Rafieisakhaei Mohammadhussein , Barazandeh Babak 
Published: March 2017

Abstract
Climate change poses a global threat to the sustainable development of human societies. If not controlled, its impacts can threaten a vast range of human life including economic, social welfare, and public health. Most of the human-made part of this phenomenon is caused by the excessive greenhouse gas emissions (GHG), particularly carbon byproducts. Several solutions have been proposed to reduce the carbon emissions. In this paper, we investigate the effectiveness of an Emission Trading System (ETS), with a case study on the European implementation of this approach.
Our approach is based on the system dynamics methodology. First, we perform a literature study on the main sources of carbon emissions, and investigate the key factors involved in the carbon cycle. Then, we extract the casual relations between the derived factors and parameters. On top of the casual model, we build a stock and flow model in which the stock variables are related to their rate variables through a differential equation whose coefficients are time-varying and determined in the model itself. The whole model is reduced to a system of differential equations with variable coefficients, and is solved numerically using methods such as Runge-Kutta. The mathematical relations between the main variables are derived using regression analysis on the available historic data which are used to train the model. For the set of variables where analytic relations cannot be derived or are not suited, look-up tables are utilized.
The main procedure involved in the ETS is providing an Emission Allowance (EA) trading system, by placing a price on the volumes of the emissions. Thereby, financially incentivizing the main entities that emit large amounts of CO2 (or other GHGs in equivalent volumes of CO2) to reduce their emissions. An economic model between the EA Price, Demand and Supply is derived, where the supply is determined according to the regulations (reduced by 1.74% annually), and the demand is proportional to the actual carbon emissions. All main sources of emissions such as the power sector (whose main player is the electricity demand), manufacturing industries and construction, transport sector, aviation, etc., are included in the demand side. For our case study, the data and reports of Eurostat are used and the model is simulated.
A system dynamic model to determine the relations between the emissions production, demand and allowance prices is provided, which implements the method described in the EU ETS. The European data is used to simulate the model. Our simulations show that the EA pricing system can be increasingly effective to control the emissions though the EA prices, by consistently covering more industries (currently only 45% are covered) and reducing the allowance allocations. The possible implications of such a system for the US are investigated.
The Carrot and the Stick of the Electronic Logging Device Mandate
Authors: Seidl John 
Published: March 2017

Abstract
The ELD mandate Final Rule was published in December 2015. While some fleets may not like the FMCSA's Stick, they will ultimately reap many benefits from the use of ELDs – the Carrot. We describe them here, and include best practices for successful ELD implementation.
Leading Indicators For Onshore Drilling HSE Outcomes
Authors: Jablonowski Christopher J. 
Published: March 2017

Abstract
This investigation specifies and estimates regression models to test several hypotheses about the operational and managerial drivers of HSE incidents with emphasis on the identification of potential leading indicator variables. A leading indicator, or precursor, provides a signal of an increase in the likelihood of HSE incidents for future activity. The results of this investigation suggest several viable candidates for precursor variables in onshore drilling, including impending rig moves, changes in supervision, and operator-contractor cumulative experience. The results empower engineering and operations personnel to intervene and initiate mitigation activities. While the investigation was completed for one operator in one geographic area, it is believed the results are generally applicable to other regions, other operators, and very likely to similar industrial sectors.
Analytical Approach to Determine the Degree of Interference Between Multi-Fractured Horizontal Wells
Authors: Molina Oscar , Zeidouni Mehdi 
Published: March 2017

Abstract
Economic development of unconventional reservoirs heavily relies on hydraulic fracturing of horizontal wells in multi-well pads. The application of this technology poses the challenge of determining optimum well spacing. For this reason, well interference analyses have recently gained increased attention in the industry.
The objective of this study is to present an analytical well interference model that is aimed to diagnose interwell communication between multistage-fractured horizontal wells (MFHW) in liquid-rich shales in a dual-well system via fracture overlapping or fracture "hits". The mathematical model is based on the application of the trilinear flow model to two parallel MFHW connected through the inner fracture tips. This situation is represented mathematically using a semi-permeable boundary condition. This condition features a constant α, called the well interference coefficient, which allows history-matching the analytical model with pressure-transient data. Once α is obtained, the degree of well interference is measured using the parameter δw, representative of the fraction of the fractures in comunication. Pressure-transient data is generated numerically for four different dual-MFHW systems with 5, 10, 20 and 50 fractured stages. Fractures half-length also changes for each case study. Petrophysical data from the Lower Eagle Ford shale found in the literature is used to build the reservoir model.
It is shown that the analytical well interference model accurately captures the characteristic pressure-transient behavior of interwell communication due to fracture hits byhistory-matching α with well data for each system. Various degrees of interference are allowed in all system so that a relationship between α and δw is established for each case. Therefore, the degrees of interference δw systematically computed by history-matching α with numerical pressure-transient data from a parent multi-stage fractured system may be extended tomulti-well systemsregardless of thenumber of fractures, so long as both wells have similar characteristics, including reservoir properties and fracture half-length.
Modeling of CO2 Flooding and Huff and Puff Considering Molecular Diffusion and Stress-Dependent Deformation in Tight Oil Reservoir
Authors: Kim Tae Hong , Cho Jinhyung , Lee Kun Sang 
Published: March 2017

Abstract
Recently, the potential of enhanced oil recovery (EOR) with CO2 injection in tight oil reservoir has drawn attention. Most of previous studies for CO2 injection in tight oil reservoir have considered only huff-and-puff process. However, CO2 flooding could show further improvement depending on the fracture-reservoir system. To investigate the effects of CO2 flooding and huff-and-puff processes in tight oil reservoir, numerical models incorporating molecular diffusion and stress-dependent deformation mechanisms were generated. In order to model the realistic tight oil reservoir, core and reservoir models were constructed with data from Bakken shale field. Coand counter-diffusive transport is depicted by Sigmund and Wilke correlation. Stress-dependent deformation in tight reservoir is considered by exponential correlation coupled with linear-elastic model. The developed models were used to investigate major factors affecting CO2 injection process such as molecular diffusion, stress-dependent compaction, and conductivity of fracture system. In the proposed model, about 8% of hydrocarbon was recovered during the primary production. Recoveries with CO2 flooding and huff-and-puff following primary production are increased to 18 and 15%, respectively. The main factor which facilitates CO2 flooding is the fracture conductivity of unstimulated zone. Because the middle Bakken formation shows relatively higher permeability and fracture conductivity than other ultra-tight reservoirs, the CO2 displaces the oil between wells with flooding. In case of the reservoir with lower fracture conductivity, on the ther hand, huff-and-puff process is better than flooding process for EOR. In addition, CO2 flooding process showed higher CO2 storage than huff-and-puff process. CO2 flooding method stores 1.7 times higher CO2 than huff-and-puff method. About 91% of injected CO2 is stored for CO2 flooding and about 54% of injected CO2 is stored for huff-and-puff. Therefore, the need to develop CO2 flooding techniques is evident in order to improve not only the oil recovery but the CO2 storage. The investigation of CO2 flooding and huff-and-puff with comprehensive numerical model suggests better understanding and design of CO2 injection in order to improve the efficiency of CO2 EOR and storage in tight oil reservoirs.
Design and Execution of an MEOR Huff and Puff Pilot in a Wintershall Field
Authors: Aditama P. , Avbelj E. , Reimann S. , Dopffel N. , Mahler E. , Poulsen M. , Jelinek W. , Alkan H. 
Published: March 2017

Abstract
Wintershall is conducting a technology project for development and field application of MEOR (Microbiologically Enhanced Oil Recovery) in collaboration with BASF. The successful results of the laboratory phase led to a first small confined pilot Huff'n’ Puff (HnP) in a Wintershall mature oil field to prove that the laboratory-developed concept works in the field under reservoir conditions.
A suitable well for the MEOR operation was selected in the studied field based on selection criteria. The selected well is a former producer approximately 900 m deep. After a USIT run it was decided to recomplete it. Prior to MEOR HnP pilot, an injectivity test was performed to allow for re-assessment of the current petrophysical and geological properties around the well. In order to establish the baseline for the pilot evaluation, a comprehensive monitoring program consisting of microbiological, chemical and petrophysical surveys commenced just after the well recompletion.
The surface set-up designed for follow-up MEOR field operations was installed in the field. The mixing of the MEOR solution with the injection water was regulated automatically by measuring the injection rate. The injection took four days, followed by an incubation period of five weeks. During the nutrient injection, the injectivity was significantly lower than the one obtained from a previous injectivity test. As a result, the total volume of injected nutrient was lower than initially planned. Nevertheless, the volume was sufficient to achieve the pilot objectives.
The injection was carried out under matrix conditions by keeping the pressure below the fracture pressure. The injected fluid temperature was somewhat lower than planned, but according to downhole measurements, still high enough for microbial growth. It was observed that there was an oxygen ingress into the system through the injection pump, however no detrimental effect was seen on microbial activity. After the shut in period, a comparable volume of the injection fluid was produced back. The tracer concentration in the back produced fluid was used to calibrate the chemical and microbiological effects of MEOR.
Maximizing the Value of Matrix Acidizing Treatments in Carbonate Reservoirs
Authors: Shirley R. M. , Zhu D. , Hill A. D. , Da Motta E. P. 
Published: March 2017

Abstract
It has been well-understood that there exists an optimal condition in matrix acidizing in carbonate formations. When a treatment is not pumped at the optimal conditions, the efficiency of the stimulation suffers. A cost-effective procedure for maximizing matrix acidizing treatment results in carbonates is proposed. This procedure includes a systematic approach to altering the acid schedule, pump schedule and the placement technique. The procedure is particularly important for high temperature or long treatment intervals where achieving optimal injection rate is difficult.
Injecting acid below the optimal injection rate in matrix acidizing of carbonates can negatively impact productivity/injectivity by significantly limiting the final skin reduction. To design a treatment that creates dominant wormholes to improve well performance, the optimal pumping rate must first be determined based on the field conditions which can be scaled up from laboratory core flood data. For cases where the optimal injection rate cannot be achieved because of the limitation of pumping equipment, this paper proposes a counter-intuitive procedure for altering the treatment design. There are means to reduce optimal injection rate for a treatment, such as changing acid concentration, acid type or additives. Reducing acid strength can lead to a slower reaction rate and deeper wormhole penetration. There is however a limit since reducing the acid strength will not only reduce the optimal interstitial velocity but also increase the acid volumes required for breakthrough because of lower acid dissolving power. If the optimal pumping rate cannot be sufficiently reduced, then the placement techniques must be modified to facilitate higher injection rates. Furthermore, the pump schedule must also consider heterogeneity and this may require the use of multiple stages. Using published core flood data along with hypothetical well designs, various acid treatments have been simulated, and the results are presented in terms of skin factor along the well length for each injection strategy. The study demonstrates the application of the proposed procedure.
The results of the study showed that in cases where the pumping rate is less than optimal, simulation results show less than optimal skin factors are predicted. When pumping at low rates, using the highest concentration of acid does not necessarily result in the most efficient wormhole creation and propagation. There is a clear limit to which reducing acid strength can benefit the degree of penetration for a given injection rate. The proposed procedure is a practical means of creating a cost effective acidizing design that not only removes formation damage but creates deep dominant wormholes that minimize the skin factor.
Waterflood Performance Diagnosis and Optimization Using Data-Driven Predictive Analytical Techniques from Capacitance Resistance Models CRM
Authors: Kansao Rami , Yrigoyen Andres , Haris Zameel , Saputelli Luigi 
Published: March 2017

Abstract
Quick evaluation of reservoir performance is one of the main concern in decision making. Time consuming data preparation and processing, and data uncertainty (geological, petrophysical, reservoir engineering) limit the use of numerical simulators in addition to long term response for reservoir management. Effective reservoir management needs quick action regarding injected fluid distribution to improve areal and vertical sweep efficiency during secondary and tertiary recovery processes. Therefore, simpler methods that provide quick results to complement or substitute reservoir simulation are important for reservoir monitoring and management. Capacitance Resistance Model (CRM) is one proven method to address the above challenges. The CRM model is based on the hypothesis that reservoir performance can be inferred from analyzing production and injection data and a simplified analytic model structure. CRM is an input-output and material balance based model that use continuity equation to quantify the connectivity among injector and producer wells, time constant and productivity indices.
In this study, a CRM model was generated to build a forecasting waterflood model by to matching historic production and injection data. After history matching, the model can be used to: (1) effectively forecast oil and water production, (2) evaluate reservoir and production-injection data uncertainties, and (3) optimize injection settings to improve oil recovery factor. CRM methodology is used as a cooperative approach to reservoir simulator generated streamlines.
Different case studies were designed to investigate the robustness of CRM by providing different levels of complexities as compared with numeric simulation results. In the first case, a constant flowing bottomhole pressure and injection rate was considered, and in the second case, changes to flowing bottomhole pressure, injection rate and productivity index per each time step were considered. The CRM was able to replicate the synthetic historic data generated using numerical simulator within a satisfactory error, i.e. less than 7% in the worst case. The CRM injector producer allocation factors were also in line to those computed using streamlines. In both cases, the CRM model showed a higher allocation factor for the injector producer pairs which had better connectivity allowing the evaluation of waterflood performance by pattern while identifying the poor sweep efficiency areas. In a later optimization exercise, a dry oil production objective function was maximized subject to the constraints in the injection system. Thus, strategies derived from CRM model increased production in the range of 12% with associated water cut reduction just by reallocating injection rates.
Increasing Drilling Operational Margins of an Onshore Mature Field in Pakistan by Including a Dynamic Drilling Modeling Approach
Authors: Vielma W. E. , Quijada R. , Feltracco D. , Mittiga V. , Mosti I. , Nergaard K. 
Published: March 2017

Abstract
Access to new reserves and subsequent production is becoming a challenging scenario for oil and gas companies all over the world. In this particular context, a major operator planned an onshore well in Pakistan (located 350km north of Karachi) as part of a revamped drilling campaign in this mature field. However, in previously drilled wells in the vicinity several drilling issues were encountered including, but not limited to, a challenging drilling window with kicks and losses. These are mainly due to formation structural conditions that require very strick control of the equivalent circulating density (ECD) and the equivalent static density (ESD) for new wells drilled in the area.
If successful operationally and if reserves prove economically exploitable, this well will be used as potential reference for future infill drilling in this reservoir. To overcome the issues and ensure the greatest potential to successfully drill this well, it was decided to use managed pressure drilling (MPD) equipment for the last two challenging well sections.
Because of this, a full dynamic drilling modelling solution was selected to support the planning phase and subsequently, the decision process during the operations. The dynamic models applied include consideration of temperature, pressure, mud compressibility and rheology as well as gel breaking effects in a transient simulation. For well control considerations a two-phase model considers both influx of the reservoir fluid and modelling of the fluid properties by equation of state as well as distribution and migration of the influx in a drilling kick scenario.
As direct result of this study, it was decided to revise and slightly adjust the optimized drilling fluid weight to better manage the ECD/ESD, thereby avoiding compromising the integrity of the well during the operations. Some of the specific parameters were re-defined based on the modelling results, providing enhanced best practices for the MPD utilization.
The implemented approach required the drilling practices to be tailored for this particular well and opened the opportunity to implement the lessons learned into the company well design process and drilling practices. For this, a multi-domain collaboration is key to minimize the uncertainty associated with the behavior of the drilling dynamics with respect to the drilling window and the overall operational system. In addition it requires the inclusion of dynamic modelling to provide a more realistic planning approach makes it possible to consider different drilling opportunities in mature fields with challenging profiles.
This paper will describe the analysis done using this dynamic drilling modelling approach, with focus on the primary and secondary well control.
Assessing the Value of Information According to Attitudes Towards Downside Risk and Upside Potential
Authors: Santos Susana M. , Schiozer Denis J. 
Published: March 2017

Abstract
The Value of Information (VoI) analysis typically assesses information opportunities to manage uncertainty. The VoI is traditionally estimated using the expected monetary value (EMV), which overlooks the decision maker's (DM) attitude towards upsides and downsides. In this study, we assess the VoI for DMs with different attitudes, under different levels of information reliability. We define attitude to be as: neutrality to upsides and downsides, aversion to downside risk, and willingness to exploit upside potential. We applied a simple and flexible formula, which incorporates EMV with lower and upper semi-deviations from a benchmark, to quantify downside risk and upside potential. We determined VoI using many uncertain scenarios to maintain interactions between parameters instead of deterministically isolating the uncertainty under analysis. To accelerate analysis and reduce computational costs, we used a set of candidate production strategies optimized for extremely different scenarios. Our case study was the UNISIM-I-D, a benchmark reservoir model with a key structural uncertainty affecting production strategy selection. We used an appraisal well as an information source, and four hypothetical DMs with different attitudes. Our results showed that these DMs value information differently, that one DM may decide to acquire information while another may not, for the same situation. In our case study, information reduced downside risk but did not increase upside potential, meaning that information was more valuable to risk-averse DMs (which was up to 20 times higher), and less valuable to DMs exclusively focused on maximizing upsides.