bluuebunny/crossref_metadata_2025_split huggingface dataset:
WIZARD: Well Infilling Optimization thorugh Regression and Data Analytics
Authors: Formato Gaetano , Onzaca Christian , Molaro Simone , Amendola Alfonso 
Published: November 2019

Abstract

Objective/Scope
The definition of the locations of new wells in mature fields is a challenging problem especially in contexts of high geological complexity and low data reliability, when running fluid-flow simulations can be extremely difficult. For this reason, we develop an innovative Surrogate Reservoir Model, based on a data-driven process, which combines Machine Learning algorithms with spatial interpolation techniques. We call our approach WIZARD (acronym for: Well Infilling optimiZAtion through Regression and Data analytics).

Methods/Procedures/Process
WIZARD is a collection of different data-driven methods for the sake of definition of new infilling well locations on the basis of the expected cumulative oil productions (after a fixed target period) of unexploited areas of the reservoir. The first method, named COSMIC, is used to find a correlation between petrophysical well properties and well productivity through a regression algorithm.
The second method, that we call WIZARDMAP, uses spatial interpolation methodologies like K-Nearest Neighbours to estimate input petrophysical well data far away the existing wells and the trained COSMIC model applied to these interpolated data to predict the expected cumulative oil productions in unexploited areas of the reservoir. Finally, predictions of WIZARMAP model are compared with the ones given by another method that we call WIZARDROC, that is a predictive model trained by using only the cumulative oil productions of the existing wells and their locations.

Results/Observations/Conclusions
WIZARD workflow is applied to a highly faulted and layered reservoir with around 460 wells and 40 years production history, for which petrophysical and production data are available. Validation tests have been performed to evaluate WIZARD accuracy to forecast expected cumulative oil productions for new wells. WIZARD geological and physical soundness have been confirmed by experienced reservoir geologists and engineers, clearly showing that the methodology is reliable and therefore can be used for t least qualitative location screening of new infilling wells. This is furtherly confirmed by the satisfying match between the oil cumulative predictions of WIZARDROC and WIZARDMAP that has been obtained, indicating that the model can be reasonably used for predictive purposes.

Novel/Additive Information
WIZARD is an innovative Reservoir Surrogate Model that, combining Machine Learning techniques with spatial interpolation methodologies, is able to provide key insights for reservoir management and development plan, by suggesting the most promising locations for the new infilling wells.
Free Span Investigation of the Longest Subsea Gas Pipeline in Indonesia Using Remotely Operated Vehicle ROV
Authors: Erfando Tomi , Septriady Dela Agung , Apriandi Tengku Said 
Published: November 2019

Abstract
Based on the geophysical survey results, some part of the pipeline were found in free spans conditions. Interpretation from the geophysical survey shows that there were at least 181 free spans area along the pipeline with the length up to 200m and some of the pipeline was shown with span almost 3m above seabed. The ROV survey was then deployed to verify the free spans area and to check the other findings from the previous geophysical survey
Verification of freespan was conducted by setting up coordinates of the suspected area on the navigation software and ROV will start its investigation from the beginning of each free span to the end of it. Dual head scanning profilers, visual cameras which were installed on each side of the ROV and in front of vehicle were used to record pipeline condition along the suspected location. Position and depth of the ROV was overlaid to the video recording and the profile of seabed and pipeline along the inspected area were recorded in the navigation software
Information derived from the ROV inspection will then compared to the geophysical survey result and the final freespan condition were confirmed and results are tabulated for further rectification if required. Generally, there were 181 freespans locations inspected by ROV. Results of freespan from Freespan #1 at KP 3.638 to Freespan #181 at KP 233.978 are listed. There are some miss leading geophysical interpretation for the sample taken at KP 101.108 to KP 101.281, where from the geophysical survey was reported that the free span was found 150.1m but from the ROV visual inspection was found that the pipeline was set on seabed at some points with a maximum distance not more than 35m. Based on the ROV visual inspection, there were 29 freespans were found more than Maximum Allowable Span (MAS)
East Java Gas Pipeline Pipeline (EJGP) is the longest offshore gas pipeline in Indoensia. It transports gas receiving from Central Processing Plant on Pagerungan Island in Kangean Islands through the Madura Strait and onshore via Porong Sidoarjo to Surabaya with the total length of offshore part is 368km. The ROV is the first to be used to inspect this offshore gas pipeline.
A Novel Lwd Tool Based on High-Frequency Electromagnetic Wave Used for Determining and Ranging Reservoir Boundary
Authors: Teng Xinmiao , Sheng Limin , Zhang Liancheng , Ai Weiping , Gao Wenkai , Yu Dezhou 
Published: November 2019

Abstract
To increase reservoir-encounter drilling ratio while horizontal directional drilling, this paper presents a novel LWD tool based on the high frequency electromagnetic wave, which can get the accurate distance between the drilling tools and reservoir boundary. While horizontal directional drilling in the reservoir, the LWD tool mentioned transmits a modulated single-frequency pulse, the pulse width is about 10ns and the central frequency is about 350MHz, by the transmitting antenna. The high frequency electromagnetic wave is reflected on the interface of the reservoir and the cap because of the dielectric difference. The reflected wave can be captured by the receiving antennas and then be processed in the designed algorithm aiding in ranging the distance of the reservoir boundary in real time. A 2.0*1.0*0.7 meters clay sand, concrete ground and a saline bag with the conductivity in 60mS/cm are designed to simulate the situations likely to be in real horizontal directional drilling operations and to evaluate the detection capability of the LWD tool in a controlled situation. Under the different conditions and distances, the measurement range of the LWD tool is about 0.7∼2.0 meters and the accuracy is less than ±3 centimeters, a high accuracy for geosteering in horizontal directional drilling, which will be greatly helpful to keep the drilling bit drilling in the optimum position of oil or gas reservoir all the time to increase the reservoir-encounter drilling ratio.
Low Salinity Water Flooding in Carbonate: Screening, Laboratory Quantification and Field Implementation
Authors: Masalmeh Shehadeh , Al-Hammadi Mohammad , Farzaneh Amir , Sohrabi Mehran 
Published: November 2019

Abstract
In recent years, low salinity flooding has attracted significant attention as a new method for improving/enhancing oil recovery for both sandstone and carbonate reservoirs. Extensive laboratory experiments investigating the effect of low salinity injection are available in the literature, which show a wide range of responses in the extra oil recovery, ranging from 0 to more than 20%. In this paper, we report experimental programs performed using cores and fluids from several reservoirs in Abu Dhabi with the objective of quantifying low salinity effect in both secondary and tertiary modes and to establish a procedure to screen reservoirs for their suitability for low salinity waterflooding.
To quantify the low salinity effect, multi-rate unsteady state flooding experiments have been performed in both secondary and tertiary mode using reservoir fluids and core material at reservoir conditions of 120 C and 4000 psi. All core floods were performed using 30 cm long and 2 inch diameter core samples. In addition, fluid-fluid interaction experiments were performed using fluids from more than 20 carbonate reservoirs in Abu Dhabi. The fluid-fluid experiments were performed to measure the water in oil micro-dispersion formed upon contacting crude oil with both formation water and low salinity water in order to screen ADNOC's oil reservoirs for suitability for low salinity waterflooding.
The fluid-fluid interaction experiments showed that a number of crude oil samples from carbonate reservoirs in Abu Dhabi were able to create micro-dispersion upon contact with low salinity water. These crude oils are called positive crudes in this paper. On the other hand, several crude oil samples did not show micro-dispersion upon contact with the same low salinity water, hence they are referred to as negative crude oils. Two positive crude oils and two negative crude oils have been used in the flooding experiments. The main conclusions of the study are: 1- The flooding experiments using positive crude oil samples have led to extra oil recovery upon injecting low salinity water, while the negative crude oil resulted in either no or little extra recovery, 2- The data base developed in this study is used for screening ADNOC's oil reservoirs for low salinity waterflooding based on fluid-fluid interaction and shows a significant potential of this promising EOR technology for carbonate reservoirs, and 3- The flooding experiments show up to 6.5% extra recovery in tertiary mode and up to 12.5% extra recovery in secondary mode.
The study presented in this paper demonstrates that the use of fluid-fluid interaction experiments and measuring the creation of micro-dispersion upon contacting crude oil with low salinity is a robust screening method for low salinity water flooding. Moreover, this screening method can lead to significant saving in both time and cost of running low salinity flooding experiments.
Understanding the Performance and Application Window of Autonomous ICD
Authors: Becerra Moreno Oscar , Gohari Kousha , Kendall Alexander 
Published: November 2019

Abstract
While it is understood that Inflow Control Devices (ICDs) can be an extremely valuable tool for reservoir management in certain applications, an engineering analysis is used to determine viability of ICDs for future developments. Typically, reservoir and production engineers use numerical reservoir simulation and/or steady state simulation to determine their applicability, evaluate various devices and configure their completions. Hence it is critical that the methods used to characterize the performance of the ICDs in these simulators are accurate.
For passive ICDs, the characterization is fit for purpose; however for Autonomous Inflow Control Devices (AICDs), despite their recent rise in popularity, the performance characterization has been limited to mathematically derived correlations that are adjusted to initial data. By using these mathematically derived correlations rather than physics-based modeling, the characterization is unable to predict critical flow for compressible fluids and critical flow caused by cavitation in the case of pure substance flow, such as water. By neglecting the effects of the physical phenomenas such as compressibility and cavitation, the simulation will result in higher gas production than reality for gas coning control applications and higher water production in thermal applications where the operational condition is close to water saturation.
Furthermore, fitting the correlations parameters for a wide range of fluid viscosities is complicated. This has led to several variants of correlation parameters that are dependent on specific ranges of viscosity. Hence, dynamic simulations can be complicated by the fact that the performance correlation factor has to be changed according to the fluid that is produced.
In an attempt to remedy these limitations, a typical AICD, considered an industry standard, was modeled using a mechanistic approach to capture the physics of the process as closely as possible. Existing sets of test data, some of which were publically available, for fluids ranging from 0.011 to 500 cP, were used to tune the mechanistic model and test the ability of reproducing the data.
The results have shown that the model has the ability to reproduce the flow loop test, effectively being able to predict compressible critical flow and performance of the device for a wide range of fluid viscosities. Furthermore, new experimental data was generated to test cavitation conditions that were included in a unified model. The unified model consolidates the expected operational window of the device, allowing accurate interpolation of non-tested conditions.
Gas Kick Simulation for Offshore Gas-Hydrate Reservoir Drilling
Authors: Liao Youqiang , Wang Zhiyuan , Pan Deng , Sun Baojiang , Duan Wenguang 
Published: November 2019

Abstract
In this research, a new gas kick simulator which incorporates the fully coupled heat and mass transfer model to describe the gas kick developing process, has been developed considering the unsteady gas–liquid–solid multiphase flow. Then, a series of numerical simulations are described to make a detail understanding of the gas kick developing process focusing on the variation of gas void fraction, pit gain and bottom hole pressure at various construction parameters. The numerical simulation results show that: fluid flow in annulus will change to gas–liquid–solid flow due to hydrate dynamic decomposition. What's worse, if there is no wellhead pressure control device, i.e. the wellhead pressure is equal to 0 MPa, the gas volume fraction and pit gain can reach 0.68 and 3.12 m3 at the wellhead, respectively. While, if the wellhead pressure increases to 0.5 MPa, gas fraction and pit gain only reach to 0.28 and 1.54 m3, respectively. Therefore, managed pressure drilling technology should be applied to hydrate reservoir drilling. On the other hand, if the mud inlet temperature is lower than 17.5 °C, which means a lower rate of hydrate decomposition, the gas volume fraction at wellhead can be safe and controllable. Compared with wellhead backpressure and inlet temperature, drilling fluid density has few effects on the gas void fraction in annulus. To sum up, in order to ensure safety and efficiency in hydrate layers drilling, a lower inlet temperature of drilling fluid and a higher wellhead pressure, such as 17.5 °C and 2 MPa, which mean a lower hydrate decomposition rate, can achieve the gas volume fraction at wellhead less than 10%. This paper provides some meaningful guidance in hydrate formation drilling process.
Evaluation of a New Barium Sulfate Dissolver and the Effect of the Presence of Calcium Carbonate in the Dissolution Rate
Authors: AlAamri Jamal , AlDahlan Mohammad , M. Al-Otaibi Fares , Al-Ghamdi Abdulaziz 
Published: November 2019

Abstract
Barium Sulfate, barite is commonly introduced into the oil and gas wells during drilling when used as weighting agent but it also can be formed at wellbore tubular during production as scale. After drilling, the barite in the wellbore and in the filter cake can cause erosion of well tubing during production, and should be removed. Dissolving and removing barite is a challenge because of its low solubility in water and hydrochloric acid. It can be removed by mechanical approaches, which includes scarping and jetting with foamed or viscose fluid to carry the heavy barite solid.
In this study, a new barite dissolving formulation was evaluated for its dissolving power and as barite and barite-based drilling fluid mud-cake removals. The dissolution rate at dynamic condition and in the presence of calcium carbonate was also evaluated for more than 72 hours reaction time. The study-testing scheme aimed to identify: the optimum solid to liquid ratio for maximum solubility, optimum soaking time at downhole temperature and solubility of mud-cake at optimum ratio and soaking time. Careflooding was also carried out to determine the rock-dissolver interaction.
The interaction between stimulation chemicals and formation rock is essential in order to understand these chemicals efficiency. The study results showed the average barite and mud-cake solubility was 276 and 167 lb/1000 gal in 24 hours at 270°F, respectively. 60% of the dissolved barite occurred in the first 5 hours soaking time. In the presence of calcium carbonate, the dissolution rate was dropped by almost 40%. The reduction started to be significant after 8 hours of soaking. Multi-stages treatments using 10 gallons of the dissolver per 1.0 lb of barite with 5 to 8 hours soaking time are expected to be more effective than one-stage treatment with a long soaking time.
A Novel Early Warning System of Oil Production Based on Machine Learning
Authors: Ma Kang , Jiang Hanqiao , Li Junjian , Zhang Rongda , Zhang Lufeng , Fang Wenchao , Shen Kangqi , Dong Rencheng 
Published: November 2019

Abstract
For mature oilfields which have entered into the high water cut stage, many stimulation measures are adopted in order to maintain the oil production. Those measures include drilling new wells, general measures, and strengthened measures. Even though the oil production increase when the measures conducted, it will cause different degrees of production decline in the next year. Due to the irrational composition of oil production in the matured field, abnormal production decline is becoming the primary problem for stable production. Establish an effective early warning system (EWS) is important to release production alarm and take necessary measures in advance. In this paper, the factors that can affect the abnormal decline are selected and the influence degree of different factors are compared by grey relational analysis. The machine learning was adopted to build the EWS. Three distinct forms of input data are considered to improve the prediction accuracy. By using the degree of deviation from normal as the input data for the prediction model have the highest accuracy. However basic machine learning model contains many input parameters which can't obtain easily. The number of input parameter is optimization based on the variation of accuracy under different input parameter number. In order to improve the prediction accuracy the artificial samples are added into the training process. The prediction accuracy of the final optimization model can reach 92%. According to the EWS the production condition of different reservoir is evaluated. The result reveals the possibility of the occurrence of anomalous decline in different reservoir which can effectively guide the oilfield production strategy. The EWS can be an effective tool in the oil production monitor in the mature oil field.
Seismic Data Management for Big Data Era
Authors: Pal Anik , Kumar Pranav , Shah Faridullah 
Published: November 2019

Abstract
Seismic data is one of earliest data acquired in a prospect evaluation and the data are utilized throughout the exploration and production stages of a prospect. With recent advances in the handling of big data, it is essential to re-evaluate the best practices in the seismic data ecosystem. This paper presents the idea to leveragingthe technology advancement in big data and cloud computing for Seismic data ecosystem with the aim to providing an improve user experience.
This new seismic platform would be capable of handling, managing and delivering the full spectrum of seismic data varieties starting from acquired field data to interpretation ready processed data. The system to have the following capabilities: Capability to entitle the right portion of data to every user as per interestOrganization of seismic data as per the business unitsData security by sharing data only with legitimate users/groups.Direct or indirect integration with all the data sources and applications who are consuming and/or generating dataSharing of and collaboration on data within company and/or across organization for shareholding partner, perspective seismic buyer for trading and relinquishment, regulatory agency resource certifying agencies and service providers etc. over limited network connectivity.Provide intergration/data deliverivey to End Users applications where this seismic data will be utilizaed
Implementation of Seismic ecosystem will enable: Sharing of seismic data by the acquisition, quality control, data processing and interpretation with user communities from one centralized storageCollaboration of stake holders in real time over an encrypted networkLeveraging cloud and mobility technology advancement for agility and interaction. The system will be connected and interactive yet has the power of complex high-performance computing infrastructure on the background.Data delivery and auditing to wider and more diverse user community that consumes data from different platforms.Secure data access based on organizational business units to make sure data does not fall into unauthorized hand.Reduction in seismic data turnaround time by reading and ingesting large volume of data through parallel input/output operation.Improved data delivery and map interface with contextual information out of the centralized data store.Augment traditional workflows with machine learning and artificial intelligence for example automated fault detection, etc.,
The proposed best practice aims to bring all of the different disciplines working with seismic data to one centralized seismic data repository and enable them to consume and share seismic data from big data lake. This is live and interactive when compared to traditional technologies of using the archive and restore system in standalone application.
In Situ 3D Characterization of the Texture of a Foam Flowing in a 3D Porous Medium
Authors: Ouali Chakib , Rosenberg Elisabeth , Barre Loic , Argillier Jean François 
Published: November 2019

Abstract
Two innovative characterization techniques, Small Angle Neutron Scattering (SANS) and High Resolution Fast X-ray Micro-tomography on a Synchrotron, have been combined to usual coreflood environments and X-Ray CT Scanner measurements in order to describe the texture of a foam flowing in an opaque 3D porous medium. SANS measurements give access simultaneously to the gas saturation and to the amount of gas-liquid interfaces developed per unit volume and therefore to the in situ specific surface area of the foam denoted S/V. In situ texture of the foam flowing in real 3D porous media is therefore measurable. Fast X-Ray micro-tomography 3D images of foam flowing in a porous medium give visual evidence of the presence of gas bubbles in areas where the flow rate is naturally slowed by the trapping phenomena and enable to describe and follow the phenomena of intermittent trapping at the pore scale.