bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pour Point Depressant Treatment via a Field-Deployable Performance Monitoring Technology
Authors: Zheng Sheng , Patel Nimeshkumar , AbouZour Mohamed 
Published: March 2019

Abstract
Waxy crude oils are commonly encountered by oil producers. Wax precipitation and the subsequent wax deposition and/or pipeline gelation are common flow assurance issues associated with crude oil production and transportation. Pour point depressants (PPD) and wax inhibitors (WI) have been proven successful in preventing gelation and mitigating deposition. However, for many reported cases, due to the lack of effective field-deployable performance monitoring technologies, PPD applications have failed to address undesirable changes in field conditions, i.e. increased pressure drop, change in fluid composition, equipment failure etc., in a timely fashion. Utilization of a field-deployable technology will allow a quick and accurate crude treatment via a suitable PPD application. This paper presents a field-deployable technology for wax risk assessment and PPD treatment monitoring. The technology is based on the characterization of the molecular interactions between paraffin chains and PPD additives using Fourier-Transform Infrared (FTIR) fingerprinting. The oil fingerprinting and data analytics can be utilized to predict the wax appearance temperature, pour point and wax deposition potential of the oil. Two polymeric pour point depressants were studied and their remarkable performance and handleability are reported.
A New Tool for Identifying Unconformities During Exploration Drilling
Authors: Ryan James , Roberts Richard 
Published: March 2019

Abstract
A powerful new tool for unconformity identification in a range of geological environments is presented together with very strong evidence of its utility.
Commonly in an exploration setting correct sequence interpretation has taken years and multiple detailed studies, now with the new tool it can be done quite easily in near real time.
Recognition of unconformities in boreholes, particularly where correlation with outcrop is not available, traditionally relies on paleontological methods, normally palynology or micropalaeontology and correlations between wells where sections of the observed sequence are missing. Observations in recently drilled wells in Dubai have provided evidence for another useful tool.
While drilling Well A, bulk rock phosphate concentrations were obtained in near real time while drilling using X-ray fluorescence (XRF). These were then plotted against well depth. Phosphate values were taken as indicators of long duration and high intensity of organic production or conversely a low rate of sedimentation. Unconformities were marked by significant and obvious phosphate peaks while drilling in a marine sequence. Higher than average concentration of phosphates in marine environments during periods of non-deposition or very slow deposition have been known for some time but their use as markers for unconformities while drilling has not been widespread due to the practical difficulties with sample analysis. With advances in XRF technology routine wellsite XRF analysis services are now available.
Plots of phosphate concentrations in Well B which was drilled through a sub-aerially deposited sequence also showed phosphate peaks, some of which correlated with known and recognisable unconformity surfaces. Further evaluation, particularly comparison with palynology data, showed that the phosphate peaks which did not correlate with known unconformities indicated previously unrecognised unconformities. Phosphate peaks on unconformity surfaces in sub-aerially deposited sequences have not, as far as the authors can determine, been previously recognised.
Well C is an older well which penetrated a similar sub-aerially deposited sequence to Well B with no XRD analyses available. Correct interpretation of the Well C sequence was not possible until the key points were derived from the more complete Well B data.
Evidence is presented showing that phosphate peaks are practical and useful indicators of unconformities in near real time, especially when interpreted with other geological information. An example is also given of an unconformity which displays no phosphate peak together with an explanation as to why there is no peak.
In an exploration setting analysis of phosphate trends can significantly enhance and simplify sequence and palaeoenvironmental interpretation and understanding of regional tectonics thus providing greater insight when planning follow up wells leading to a higher success rate. As such it is a new and novel exploration tool with a potentially high economic value.
AccuPipePred: A Framework for the Accurate and Early Detection of Stuck Pipe for Real-Time Drilling Operations
Authors: Magana-Mora Arturo , Gharbi Salem , Alshaikh Abrar , Al-Yami Abdullah 
Published: March 2019

Abstract
Thorough preplanning and best drilling practices are effective in reducing stuck pipe incidents, data analytics offer additional insight into further reducing the significant non-productive time (NTP) that results from this unplanned event. The severity of the stuck pipe problem may stop the drilling operations for a short time, or in more difficult cases, the drill string has to be cut and the borehole is sidetracked or plugged and abandoned. Consequently, detecting the early signs of this problem, in order to take the right actions, may considerably or entirely reduce the risk of a stuck pipe.
Although computational models have been proposed for the early detection of the stuck pipe incidents, the models are derived from a reduced set of wells with stuck pipe incidents, which may result in under-trained models that predict a large number of false positive alarms. A sufficient amount of data or wells that statistically represent the parameters surrounding stuck pipe incidents under different circumstances is required in order to derive a generalizable and accurate prediction model. For this, we first derived a framework to automatically and systematically extract relevant data from the historical data. As such, our framework searches through the historical data and localizes the surface drilling and rheology parameters surrounding the stuck pipe incidents. Moreover, we performed feature selection by selecting the top-ranked parameters from the analysis of variance, which measures the capability of the drilling and rheology parameters to discriminate between stuck pipe incidents and normal drilling conditions, such as, weight on bit, revolutions per minute, among others.
Using the relevant features selected by the analysis of variance, we derived a robust and fast classification model based on random forests that is able to accurately detect stuck pipe incidents. The implemented framework, which includes the automated data extraction module, the analysis of variance for feature selection, and prediction, is designed to be implemented in the real-time drilling portal as an aid to the drilling engineers and the rig crew in order to minimize or avoid the NTP due to a stuck pipe.
Numerical Approach in Analyzing Pressure Transient Responses in Dual-Porosity Dual-Permeability DPDP Reservoirs
Authors: Alramadhan Aymen A. , Guerrero Rodolfo J. , Alzahrani Abdulrahman M. , Al Awami Bassam A. 
Published: March 2019

Abstract
Advancements in numerical well testing packages in interpreting pressure transient behavior of complex well geometries and reservoir structures have lead to an improved understanding of the multi-scale heterogeneity encountered in dual-porosity dual-permeability (DPDP) reservoirs. This paper demonstrates the power of numerical well testing models in handling conceptual cases of increasing complexity in dual-porosity dual-permeability (DPDP) reservoirs where a high permeability matrix system interact with super-k intervals, fractures, and faults systems with different levels of complexity.
Numerical well test models are built using data from multiple scales and sources (image logs, flowmeter responses (PLTs), petrophysical logs (FALs), and seismic attributes) to match pressure transient responses of wells completed in dual-porosity dual-permeability reservoirs. Six generalized conceptual cases are presented in this paper; a vertical power water injector that initiated induced fractures due to injection above fracture pressure, a vertical well near an area of intersecting faults, a 40-degree deviated well intersecting diffuse fracture network, a deviated well near a conductive fracture corridor, a horizontal well intersecting a finite conductivity fracture, and a horizontal well intersecting an infinite conductivity fracture. An integrated approach was used to match the pressure responses in all cases.
Experience shows that the most representative well test solution comes from a thorough integration of well-test data with all available static and dynamic data (e.g. image logs, flowmeter responses (PLTs), geophysical, and petro-physical data). In addition, inclusion of pressure transient responses of offset wells in the area understudy as part of the analysis is crucial in choosing the most representative well test model.
In summary, this paper provides guidance and best practice to reservoir engineers in building numerical well test models to analyze fracture and matrix responses in dual-porosity dual-permeability (DPDP) reservoirs. Conceptual cases emphasize integration of multiple sources of static and dynamic data to model different well responses.
Back-to-Basics Gives New Lease on Life to a Reservoir
Authors: Bardalaye Jayanta , Salem Salah , Al Ghani Sayed , Al Sadadi Ahmed , Nedham Najla 
Published: March 2019

Abstract
The onshore Bahrain Field is a multi-reservoir oil and gas field in the Kingdom of Bahrain. Hydrocarbons are found in various stratigraphic intervals from Devonian to Upper Cretaceous in mostly carbonate reservoirs. Clastic reservoirs are scarce in the post-Permian section but dominate in the pre-Permian section. The Lower Cretaceous Kharaib Limestone is an oil reservoir. The unit was tested in different exploratory wells in the early life of the Bahrain Field and it was found to be of low permeability but produced oil.
The first phase of field development in Kharaib was initiated in the 1970s and after an initial period of dry oil production, the wells produced for a long time with high water cut (more than 90%). In the early 2000s, a horizontal well drilled in the reservoir provided encouraging results. Main development activities started from 2010 onwards, after Tatweer Petroleum – Bahrain Field Development Company W.L.L. ("Tatweer Petroleum") was formed. Thirty horizontal and fifteen deviated producers (a total of forty-five wells) were drilled during the period 2010–2014 and as a result, oil production from the reservoir increased significantly. However, within a short period of time, most of the wells started producing with high water cut (more than 90%) and image logs recorded in many horizontal wells showed presence of fractures. Based on this observation and 3D seismic analysis, Kharaib was characterized as a fractured reservoir and high water production was attributed to it. Later on, many wells had mechanical failure due to casing corrosion developed against the shallower Shuaiba aquifer. All development activities were subsequently stopped for the reservoir due to economic risk.
In 2016, a renewed effort was undertaken to analyze all past data including; regional tectonics, core data, 1970s build-up studies, cement integrity, and image log interpretations. This back-to-basics analysis indicated that the primary cause of high water production in the Kharaib wells is lack of zonal isolation with Shuaiba (casing corrosion wells excluded) and not due to the presence of occasional fractures.
Development activities restarted in 2017 that focused on addressing the zonal isolation and casing integrity issues. Seven wells have been drilled to date producing with an average water cut of 22%. More development wells are planned in the future thereby giving a new lease on life to the reservoir.
Investigate Proppant Transport with Varying Perforation Density and its Impact on Proppant Dune Development Inside Hydraulic Fractures
Authors: Ba Geri Mohammed , Imqam Abdulmohsin , Suhail Mohammed 
Published: March 2019

Abstract
Proppant transport adequately during hydraulic fracturing treatment assumes same perforation contribution through multi-perforation system. Proppant transport performance into the different ordination fracture system using multi-entry perforation technique is still not fully understood. This experimental study was aimed to deeply investigate five factors that affect proppant transport performance: number of perforations, perforation opening size, shear rate, fracture orientation, and proppant size distribution. The impact of these factors on proppant transport performance from different perspective was studied. Fracture slot model was designed and built to observe easily the effects of perforation density and fracture orientation. The results of this experimental work show that limited-entry perforation technique has significant impact on proppant transport within fractures where single top perforation had better proppant placement than multi-perforation system. Fracture area was approximately propped with 66% and 48% using top perforation and multi-perforation system, respectively. Slurry with high shear rate has a negative effect on the proppant equilibrium dune level (EDL) and fracture propped area (FPA). Fracturing treatment using high shear rate causes high pressure drop in the fracture that leads to decreasing EDL by 17% and fracture propped area by 23% comparing to using low shear rate. Using large proppant size (20/40) leads to form high EDL and FPA compared to 100 mesh size. Proppant transport dominated by four mechanisms and the vertexes near wellbore plays main mechanism to carry proppant farther inside the fracture.
A Novel Method for Characterizing the Dynamic Behavior of Proppant Pillars With Fracture Closure in Pulse Fracturing
Authors: Lu Cong , Li Zhili , Zheng Yunchuan , Yin Congbin , Yuan Canming , Zhou Yulong , Zhang Tao , Guo Jianchun 
Published: March 2019

Abstract
The pulse fracturing is widely used in unconventional reservoirs. It alternately pulse pumping the proppant slurry and clean fluid to form discontinuous placement proppant pillars in the artificial fractures and the pulse fracture conductivity is several orders of magnitude higher than conventional hydraulic fracture conductivity. However, the understanding of the deformation law of proppant pillar under the action of closure pressure and proppant normal stress is unclear, resulting in difficult to calculate the fracture conductivity and prefer proppant.
Firstly, replacement construction and experimental displacement by Renault Similarity Criteria, three typical proppant pillars placement structures are extracted through the large-scale visualized flat plate device. The Young's modulus of the proppant pillars are calculated in modified API conductivity cell. Secondly, proppant pillars are dispersed into particles by the Smooth Particle Method (SPH). Using the parameters obtain from the above experiments, fracture-proppant pillar contact models are established to simulate the deformation process of proppant pillar and get normal stress of proppant particles. Thirdly, extracting the shape of stabilized proppant pillars, establish the fracture-proppant pillar flow model, calculate the fracture conductivity in different closure pressure.
The simulation results show that as the closure pressure increases from 14MPa to 41MPa, the fracture width present an accelerated downward trend, The fracture width under the support of the initial radius of 9 mm proppant pillars are the largest, decreasing from 2.52mm to 1.72mm, the larger the radius of the proppant pillar, the greater the fracture width, the normal stress of three types of proppant pillar particles are both changed from 73MPa to 110MPa. The elliptical cylinder proppant pillar has the largest fracture conductivity. Its fracture conductivity is reduced from 12500D•cm to 3630D•cm. The larger the construction displacement and the pulse time of proppant slurry, the greater the fracture conductivity.
The model in this article can calculate the normal stress of proppant particle and fracture conductivity in different closure pressure, which can significantly guide the choice of construction parameters and the type of proppant.
Production Logging Using Quantum Dots Tracers®
Authors: Anopov Alexey , Ovchinnikov Kirill , Katashov Alexander 
Published: March 2019

Abstract
Conventional production logging tools proved to be efficient in vertical wells. When it comes to work in horizontal laterals production logging becomes much more complex. Common challenges are layered flow of reservoir fluid, deviation, wellbore accessibility, and stagnant zones along lateral. The tracer technology features a synthesis of a combination of marker-reporters made of a few quantum dots and a mixture of the polymer-based chemical composition. Quantum dots are nanocrystals produced using the process called colloidal synthesis. A single quantum dot is compounded of few hundred atoms and as small as 2-10 nanometer in diameter. Colloidal quantum dots irradiated with a laser emit light of different colors due to quantum confinement. The emittance of a particular specter of light can be detected using flow cytometry method. Several quantum dots joined together creates a unique and traceable marker-reporters element. There could be many unique tracer signatures (over 60). Utilization of quantum dots exclude any chance of misinterpretation while identifying tracers in samples of formation fluid. To achive superior accuracy in tracer identification we use software based on "machine learning". Qualitative and quantitative analysis of quantum dot marker-reporters in samples of formation fluid allows making informed conclusions about the performance of productive intervals of a horizontal well. Application of the technology showed the following benefits: the possibility of monitoring inflows for a long time, in contrast to a one-time logging operation; a significantly lower resource intensity and cost; confidence in conditions when the traditional downhole logging operations are complicated. Quantum dot tracer technology allows solving a number of problems, such as: post-fracturing inflow profile evaluation extended in time; assessment of each production interval in regard to water and oil production; optimization of technical solutions for well completions in the early stages of field development, such as number of ports; analysis of hydrocarbons extraction ratio; detailed information in the analysis of mutual influence of neighbouring wells in the oilfield. The application of the technology is particularly effective in the early diagnosis of water breakthrough, which allows enough time to choose the right technology for water shut off operation. Ultimately, this fact reflects in declining production rates and increasing incurred costs Major benefit is an ability to monitor production per zone at any time during five (5) years after deploying tracer-containing material downhole. Implementation of the technology is time efficient and does not require field equipment as well as crew for operation, which reflects on operating costs carried by customers.
Increasing Efficiencies During Cased Hole Fracturing Operations Through Frac Plug Material Selection
Authors: Wright Beau , Parekh Yash , Casanova Gabriel 
Published: March 2019

Abstract
Plug and Perf (P&P) still remains one of the most prolific methods used in multi-stage hydraulic fracturing operations. Recent changes in the materials chosen to manufacture frac plugs is leading to increased efficiencies during installation as well as the plug milling phase of P&P operations.
Historically, the fluid diversion devises used in multi-stage hydraulic fracturing operations have been manufactured using mainly glass/epoxy based composite materials and in recent years, in an effort to increase efficiencies, disintegrating materials. Most efforts have been focused on reducing the amount of metallic parts as well as reducing the overall amount of material used to manufacture these plugs in an effort maintain plug performance during fracturing operations while reducing time/costs during post-frac milling operations by making plug removal more efficient.
Recent advances in metallic based composite materials are allowing for plugs to be manufactured out of light weight alloys that are higher strength than traditional composite plug materials while also being easier to remove and circulate out during plug milling operations. Also, because the materials are not designed to disintegrate, there is no need to consider fluids that the plugs will be exposed to thus ensuring a high performance plug without the careful balancing act between an environment that causes the plug to disintegrate too fast or not at all. In addition to this, changes in how slips and packing elements are being designed is allowing for additional gains in efficiencies during plug deployment and removal.
Using real-world results, we can now demonstrate how these design changes can allow for a new level of operational efficiencies not previously available in P&P operations.
ASP Flood With Novel Mixtures of Anionic-Cationic Surfactants for High Water Cut Mature Sandstone Reservoir: From Laboratory to Field Application
Authors: Li Yingcheng , Kong Bailing , Zhang Weidong , Bao Xinning , Jin Jun , Wu Xinyue , Liu Yanhua , Wang Yanxia , He Xiujuan , Zhang Hui , Shen Zhiqin , Sha Ou , Yang Weimin 
Published: March 2019

Abstract
Cationic surfactant is never used in Enhanced Oil Recovery (EOR) for negative charged sandstone reservoirs because of high adsorption. Since January 2012, the first field scale application of alkaline surfactant polymer (ASP) flood in the world with thermal stable, highly efficient mixtures of anionic- cationic surfactants (S) for super low acid oils, was carried out in Sinopec for a high water cut mature sandstone reservoir with approximately 8,000 mg/L total dissolved solids (TDS), temperature of 81°C, to demonstrate the potential of this novel surfactants to recover residual oil from as high as 53.3% recovery percent of reserves. The maximal water cut decreased from 97.9% to 90.2%, along with peak daily oil production increased from 23.0 t to 106.1 t. The cumulative incremental oil by ASP flood at the end of December 2018 is about 276.1 kt and the oil recovery was increased by 10.65% OOIP. The estimated ultimate oil recovery can be increased by 14.2% OOIP and yield up to 67.5% OOIP.