bluuebunny/crossref_metadata_2025_split huggingface dataset:
Applying the Integrated 3D Acid Fracturing Model Using a New Workflow in a Field Case Study
Authors: Jin X.. , Zhang Hui , Yin Guoqing , Han Xingjie , Zhu D.. 
Published: November 2017

Abstract
Acid fracturing stimulation involves several major steps; a hydraulically induced fracture is created by pad fluids first, then reactive fluids are injected into the fracture, often alternating with a viscous pad to create etched fracture length. When pumping stops, the fracture closes up, and conductivity is created by an uneven fracture surface. An integrated modeling approach is introduced to simulate acid fracturing processes and diagnose operation problems. The integrated design/diagnose approach includes a fracture propagation model for fracture geometry, an acid transport model and a well performance model. The fracture geometry model is coupled with a 3D acid fracturing model to simulate acid transport and the resultant fracture conductivity. The fracture conductivity is then utilized in the well performance model to predict the well productivityafter treatment. This simulated well performance can be used to match the production data to verify the models. In this field case study, we did not have the information about formation leakoff to start the fracture geometry model. To successfully analyze the well treatment, a three step inversion workflow was proposed. The inversion workflow started from estimating a skin factor after stimulation by matching the production data. This skin factor was then converted to a fracture length that resulted in the production history. A pseudo 3D fracture model was used to predict fracture geometry. With the fixed length as a constraint, we varied the leakoff coefficient until we obtained the correct geometry. The simulated fracture geometry from the fracture propagation model was used as an input in the 3D acid fracturing model to simulate the fracture conductivity profile. The conductivity was confirmed with the fracture conductivity from lab experimental test result. To close the analysis loop, the conductivity should also be consistent with the one used in production history matching.
Fracture geometry was generated by the commercial software, MFrac, and acid fracturing was simulated by a 3D model developed before. Two wells are selected for the field case study to illustrate the application of the approach, with one well has improved productivity after acid fracturing, and the other has no response after acid fracturing. By applying the inversed integrated 3D acid fracturing modeling workflow, it showed that the well with high productivity had a fracture conductivity resembling the conductivity values fromthe experimental lab measurements. The well with low productivity showed poor fracture length and width, leading to a low production.
Acid-Fracturing Unlocked the Production Potential of Tight Tuba Carbonate Reservoir, North Kuwait
Authors: Al-Hassan A.. , Abdel-Basset M.. , Al-Enizi B.. , Al-Mosailkh S.. , Al-Qenae A.. , Saleem E.. 
Published: November 2017

Abstract
This paper will demonstrate how the acid fracturing stimulation using different technologies in multidisciplinary team integration helped un-locking the production potential and setting up development strategy for Tuba tight carbonate reservoir, with case histories.
Upcoming Reservoirs in North Kuwait (NK) oil fields will play significant role for meeting NK's strategic production target. Recent full field study of Tuba carbonate reservoir makes it the largest Oil in-Place of the Upcoming Reservoirs in NK.
Tuba, though discovered in the 60's, is still relatively under-exploited presently with only 12 active wells with very low total production rate compared to other reservoirs. High reservoir heterogeneity, tightness and poor fluid properties necessitate the move from conventional matrix stimulation to Acid Fracturing technology targeting better Frack conductivity and deep penetration for effective productivity and recovery enhancement. With efforts of multidisciplinary team, Acid Frac fluid, diverter and high leak off control technologies have been designed and executed successfully in 9 wells (7 vertical and 2 multistage horizontal) covering multiple reservoir layers with very positive results that proved the concept and supported more TUBA development.
Many technical and operational challenges were faced and properly handled with lessons learned are to be considered in next designs and executions.
Despite the close results yielded from the multistage acid fracturing in two horizontal wells compared to the results from 7 vertical wells, it is still early to evaluate stimulation potential of horizontal against vertical wells. It needs more production history and more wells to evaluate long term sustainability.
The results of such evaluation will formulate the drilling, completion and stimulation development strategy for the entire TUBA reservoir including early fracturing stimulation to improve initial productivity that will contribute significantly to the NK production target.
Near Wellbore Characterization from Temperature Transient Analysis: Accounting for Non-Darcy Flow Effect
Authors: Mao Yilin , Zeidouni Mehdi 
Published: November 2017

Abstract
Temperature transient analysis is evolving to implement the production induced thermal perturbations for reservoir and near wellbore characterization purposes. To observe strong temperature signals, temperature well testing often involve high drawdown, which may induce non-Darcy flow effect in the near wellbore region. The existing analytical solutions for temperature transient analysis generally assume Darcy’s law for pressure profiles, which can be invalid in both gas and oil productions. In this study, we derive an analytical solution for temperature transient analysis of slightly compressible fluid producing from a vertical well considering the non-Darcy flow effect. To validate the developed analytical solution, we model the sandface temperature signals analytically and verify the results with numerical simulation conducted under comparable conditions in non-damaged and damaged reservoirs. Good agreements are achieved between analytical and numerical modeling results under different production rates and non-Darcy flow coefficients. The non-Darcy flow effect significantly increases the sandface temperature variations during production, which approach to a constant increment for sufficient long production time. We develop a new permeability estimation method considering the non-Darcy flow effect, which is also applicable for damaged zone property and non-Darcy flow coefficient estimations. Two criteria to apply temperature transient analysis for non-Darcy flow effect evaluation are revealed as critical Forchheimer number and accuracy of the downhole temperature monitoring system. Sensitivity analyses reveal that the non-Darcy flow coefficient impacts the magnitude of the sandface temperature signals while the production rate affects the slope of temperature profiles in a semi-log plot. Based on the findings in this work, we build on the existing characterization procedures for temperature transient analysis and incorporate the non-Darcy flow effect to estimate the permeability and non-Darcy flow coefficient. For the cases presented in this study, the inversion process of temperature transient analysis can accurately estimate the reservoir and damaged zone permeabilities, as well as damaged zone radius (less than 10% errors). We also evaluate the non-Darcy flow coefficients with acceptable accuracies (less than 30% errors) in a field scale. With these improvements, the applicability of temperature transient analysis using analytical solutions can be extended from cases with limited sandface temperature signals of a few degC to stronger signals of 30-40 degC considering the non-Darcy flow effect.
Dual-Horizontal Wells SAGD Start-Up Technology: From Conventional Steam Circulation to Rapid and Uniform Electric Heating Technology
Authors: Xi Changfeng , Qi Zongyao , Jiang Youwei , Han Wenlei , Shi Lanxiang , Li Xiuluan , Wang Hongzhuang , Zhou You , Liu Tong , Du Xu 
Published: November 2017

Abstract
Conventionally, the start-up method of dual-horizontal wells SAGD is steam circulation. During circulation phrase, the minimum circulation time and maximum heat communication uniform profile are expected to achieve high oil production. Generally, circulation phrase takes 2 to 3 months in Canada in high quality reservoir. For the poor quality reservoir, circulation time will be longer, for example, in China it takes 200-300 days. In order to solve the disadvantages about longer preheating time and preheating ununiformity of the conventional steam circulation method, the electric preheating method is researched, super-longer integrated coiled tubing electric heater is put down to the horizontal wells separately to heat oil formation uniformly.
The heating mechanism of electric heating method is mainly based on the high temperature heat conduction. The method is less influenced by the permeability of reservoir and the viscosity of crude oil, and the heating efficiency is high. Studies show that the electric preheating method is uniform along the entire horizontal section, the effective heating inter-communication between two wells can reach to 100% theoretically, and the preheating time can greatly shortened. The optimizing results in Block Z1 of Xinjiang Oilfield indicate that the electric preheating time of SAGD is 90 days while the steam circulation time is more than 200 days and the inter-communication profile is 100%. The cost of preheating start is reduced from 420,000$ of steam circulation to 220,000$.
Success and Lessons Learned from Polymerflooding a Multilayer and Strong Heterogeneity Complex Mature Oilfield - A Case Study from North China
Authors: Wu Xingcai , Hou Shoutan , Ran Aihua , Zeng Qingqiao , Ai Huachuan , Li Kun , Jiang Haitao , He Dehai , Huang ZhiJia , Wei Na , Wang Yue , Xu Hanbing , Cui Guoyou 
Published: November 2017

Abstract
HBDY is a sandstone reservoir, which is vertically multi-layered, severe heterogeneous, and developed with water flowing channels. The injecting-production well patterns are imperfect. It has high recovery degree, 36.2%, and high water cut, 83.9%. The average reservoir crude oil viscosity is 6.3 mPa.s. The reservoir temperature is 90°C, and the formation water salinity is 10701mg/L. A new particle-type polymer slug combined with a linked polymer gel (LPG) pre-set slug was applied during May, 2014 to Feb., 2016, and technical and economic success was obtained.
The application area is composed of 12 injection wells and 29 production wells, among which 14 producers have got benefit from dual directions or multi directions. Tracer test was applied for accurate identification of areal reservoir heterogeneity. And water injection profiles were also tested to identify inter-layer difference of injectivity. Based on the above, core flooding experiment and numerical simulation were applied to optimize and design the combined slug parameters of new polymer flooding.
Tracer testing showed a relatively large difference of water flooding velocity in different directions within the same well pattern, with the lowest velocity of 1.35 m/d and the highest velocity of 7.04 m/d. It also showed over 30 times of inter-layer water intaking and liquid producing intensity as inter-layer differences. Using produced water to prepare the liquid, the total designed volume of slugs was 0.06 PV, in which the main slug was made of the nanometer-level new particle-type polymer SMG with the concentration of 0.3%, and the pre-set conformance control slug applies LPG with the concentration of 1.2%. During the execution, due to the poor gelling quality of the LPG, the preparing water for LPG slug was changed to clean water, but the SMG slug was still prepared by produced water. SMG diameter was adjusted to mirometer level from nanometer level. So far, the project has obtained cumulative oil incremental of 35,154.4 t and income of 11,469,000 USD. The operation cost per ton oil produced is 12.6 USD, and the input to output ratio is 1:4.9. Even calculated under low oil price of 30 USD/bbl, the input to output ratio can reach 1:3.3. The project is still in the effective duration, and the technical and economic effect is significant.
It has proved by the case study that good technical and economic results can be achieved through new comprehensive EOR techniques for complex mature fields with late-stage development. The scientific nature of the program design and the timely adjustment during program execution play important role in making the project successful. The experience and lessons learned from the case study provide valuable referencing significance for further optimizing and applying the technology.
Compositional Simulation of CO2 Storage in a CO2 Flooded Carbonate Reservoir
Authors: Bender S.. , Akin S.. 
Published: November 2017

AbstractCO2 emissions can be reduced by storing it in underground geologic formations such as coal seams, mature or depleted hydrocarbon reservoirs and deep saline aquifers. The combination of carbon dioxide enhanced oil recovery and permanent CO2 storage in mature oil reservoirs has the advantage to project economics. In this research, CO2 storage capacity of a CO2 flooded mature oil reservoir was estimated and the contribution of the CO2 injection to oil recovery was determined by conducting a full-field compositional simulation study. Detailed reservoir characterization study was done to build the geologic model. Reservoir fluid was characterized by sticking laboratory observations. 3-Parameter Peng Robinson EOS was used. Fugacity equilibration method was used to calculate CO2 partitioning between oil and gas. Performing the study in a CO2 flooded reservoir increased the reliability of the predictions by accurately history matching the 30 years of production and 10 years of CO2 and water injection periods. Simulation results showed that applying the CO2 storage project in an almost depleted oil field should increase the field's life and high amount of CO2 should be sequestered. Most of the sequestered CO2 was trapped by structural and stratigraphic trapping mechanism and contribution of solubility trapping mechanism is lower.
Carbonate Reservoir Waterflood Efficiency Monitoring with Cross-Well Pulse-Code Pressure Testing
Authors: Myakeshev N.. , Aslanyan A.. , Farakhova R.. , Gainutdinova L.. 
Published: November 2017

Abstract
The key parameters in water flood planning are permeability and formation thickness which define both water front propagation and pressure support.
The fluid flow in low permeability carbonate reservoirs is often happening through micro-fractures which are difficult to capture with cores and when captured are not abundant in statistics and usually not representative for porosity correlation. This leads to difficulties in modelling, forecasting and specifically water-flood planning.
Pressure interference testing is well known approach to capture cross-well permeability and thickness in-situ. But usual well testing procedures require shutting down receiving wells which is punishing for production targets. This well known problem may be addressed with high resolution quartz gauges and pulse-code decomposition mathematics which allow receiving wells to produce normally while recording the pressure data and then decipher the response from a generating well.
CO2 Tracer for Gaslift Surveillance and Optimization
Authors: Sidek Sulaiman , Idris Khairul Nizam , Lin Kellen Goh , Liang Tan Kok , Moustafa Azam Moustafa , Hwa Jason Kok , Zakaria Mohd. Zulfadly , Kamaludin Mohammad Faris , Peacock Larry , Ting Khong Kheng 
Published: November 2017

Abstract
Production Surveillance is a key activity carried out by oil and gas operators in the quest to maximize production. In Malaysia, specifically the East Malaysia Region, most of the wells in production are operated with the assistance of gaslift. Gaslift is an artificial lift method which involves injecting high pressure gas from the casing to enter the tubing via gaslift valves. Gaslift often hides inefficiencies, however by monitoring the operating conditions at the surface, an engineer will be able to obtain some clues on the performance of a gaslifted well.
Before the introduction of CO2 tracer technology, the only method available to operators to determine if a gaslift valve is open or closed downhole is to run a Flowing Gradient Survey (FGS) in order to determine the pressures and temperatures of the fluids in the tubing. Using a FGS in a well involves certain risk as it requires well intervention by running electronic memory gauges either on wireline or slickline to acquire data from a flowing well. There are also times where a FGS survey is inconclusive if the well is surging and have large changes in the surface pressures.
Since this is the fisrt such application in the field, two gaslift wells were surveyed for pilot application. The CO2 tracer technology is very effective for quick and reliable determination of lift gas entry points in the well. The technology allows the operator to detect the operating lift depth, detect multiple points of injection and even detect tubing leaks. This technology can be used as an alternate to FGS for the following advantages: Minimum equipment hook-up and no need to shut-in or choke the well, thus minimize production deferment.No wireline tools introduced into the wellbore, thus eliminate well intervention risk.Suitable for wells where a FGS is not possible due to well slugging, significantly deviated or with downhole obstruction.Possible to run survey on dual string wells to determine the gaslift split factor of a dual completionPossible to determine exactly how much gas is injected through each injection point of a well
This paper will describe the project objectives, the well candidate selection criteria, explain the execution of the survey and interpretation of the results and the value gain from implementing the recommendations from the survey results.
New Integrated Technology for Full Production and Facilities Modelling and Optimisation
Authors: Woodman MR , Rodriguez J , Wade KC , Samsatli NJ 
Published: November 2017

Abstract
In the current climate of continuing low oil prices and with many fields in decline, it is becoming increasingly important for operators to maximise daily production of oil and gas. Ideally this needs to be done with low or minimal capital investment. Many different ways of achieving this have been documented in the literature, ranging from reservoir management through well work, offline data-driven and physics-based modelling to advanced control.
In this paper, we focus on the use of physics-based models and mathematical optimisation to maximise production through the identification of operational changes on the asset, whilst satisfying the operational constraints and without adversely affecting long term reserves recovery. Our emphasis is on physics-based (rather than statistical) models, since these are designed to predict how an asset will operate in regimes where it has never previously been operated. This allows the identification of new regimes, which may be counter-intuitive, in which increased daily production can be achieved.
Surfactant Effects on Creeping Bentgrass and Annual Bluegrass Exposed to Different Irrigation and Traffic Stress Treatments
Authors: Laskowski Kevin , Frank Kevin , Merewitz Emily 
Published: November 2017

Core Ideas
Automated irrigation can be set below optimal levels while using a soil surfactant.A soil surfactant decreased soil water content when targeting above ideal irrigation.A soil surfactant increased turf quality and normalized difference vegetative index.Turf quality, under foot traffic, is improved with the use of a soil surfactant.
Creeping bentgrass (Agrostis stolonifera L.) and annual bluegrass (Poa annua L.) are turfgrass species that experience water and excessive foot traffic stresses on putting greens. The objective of this study was to investigate whether a soil surfactant would play a role in promoting tolerance to excessive water, water deficit, and traffic stress on annual bluegrass and creeping bentgrass sand‐based rootzone putting greens. A soil surfactant was applied as a foliar spray (18.5 L ha−1) to creeping bentgrass cultivar Penn A‐4 and annual bluegrass field plots and watered‐in under three target soil volumetric water contents (SWC) (8, 12, and 16% SWC). Foot traffic was applied in summer 2013 and 2014 with a traffic simulator to represent low traffic (5688 rounds of golf), moderate traffic (11,376 rounds of golf), and no traffic (control). The effect of a soil surfactant on turfgrass quality, normalized difference vegetation index (NDVI), and SWC at two depths was measured. Statistical interactions existed between soil surfactant application and target SWC. Soil surfactant‐treated turfgrass affected SWC differently across irrigation regimens, with suboptimal (8% SWC) and excessive (16% SWC) resulting in increased and decreased moisture retention, respectively. Turf treated with a soil surfactant had greater turf quality than the untreated control in late summer in each year. A soil surfactant can increase annual bluegrass and creeping bentgrass turf quality during water deficit, excessive water, and/or foot traffic conditions.
A participação feminina na transformação da história patriarcal: dimensões poder e desenvolvimento como liberdade
Authors: Faria Josiane Petry 
Published: November 2017

<p><strong>RESUMO</strong></p><p> </p><p> </p><p>A investigação tem objetivo trabalhar a problemática da participação feminina na história patriarcal e verificar as dimensões do poder e do gênero, bem como compreender a dinâmica da relação dominação/submissão para a propositura de políticas públicas. Para tanto, se recorrerá a um método dedutivo de abordagem e técnica de pesquisa bibliográfica. Os resultados encontrados confirmam a hipótese de que na contemporaneidade precisa-se reconsiderar a estatização nas relações de poder e afirmar uma pedagogia emancipadora de deliberação sociopolítica. Há necessidade da construção de políticas públicas não conflitivas, audazes e sensíveis, uma vez que sem conhecimento e liberdade não há inclusão social ou equilíbrio nas relações de poder, mas manifestação de dominação. O respeito à diversidade de gênero é imprescindível para o reconhecimento da participação feminina na história patriarcal, servindo de núcleo valorativo de políticas públicas orientadas para o desenvolvimento como liberdade, o que significa transformação radical nas relações de poder, modificação essa necessária e premente.</p><p> </p><p><strong>PALAVRAS-CHAVE: </strong>desenvolvimento como liberdade; dimensões do poder; diversidade; participação feminina; reconhecimento.</p>
A violação dos direitos fundamentais das crianças e a reprodução da violência simbolica através dos contos de fada
Authors: Cardoso Vitória Cândido , Pazó Cristina Grobério 
Published: November 2017

<p>Este artigo tem por objetivo analisar o impacto dos Contos de Fada no desenvolvimento da subjetividade da criança e do adolescente, bem como a consequente reprodução de padrões culturais eurocêntricos. São utilizados, para essa análise, conceitos estabelecidos por Pierre Bourdieu, como os de violência simbólica e <em>habitus</em>, dentre outros<em>.</em> O artigo demonstra a partir da análise da Constituição Federal e do Estatuto da Criança e do Adolescente a violação dos direitos fundamentais das crianças produzida pelos contos de fadas. </p>