bluuebunny/crossref_metadata_2025_split huggingface dataset:
Study on Rising Velocity of Methane Bubble in Deepwater Wellbore During the Shut-In Period
Authors: Li Hao , Sun Baojiang , Gao Yonghai , Guo Yanli , Zhao Xinxin , Wang Jintang , Wang Jin Bo 
Published: November 2017

Abstract
The formation of hydrate membrane on the methane bubble surface could occur in the high pressure & low temperature wellbore during the shut-in period. Using an empirical drag coefficient model to investigate the laws of methane bubble with hydrate membrane rising in drilling mud is important for calculating the well control safety operation cycle time in avoiding typhoon. The drag coefficient for methane bubble with hydrate membrane rising in mud within a wellbore was experimentally investigated using a vertical, cylindrical wellbore with high pressure & low temperature. A high-speed camera was used to obtain the process of methane bubble with Methane hydrate membrane (MHM) rising under 6 MPa & 4 °C. The velocities of bubbles were measured by image processing software. The drag coefficients of different bubbles were calculated and the variation law of drag coefficient with Reynolds number was obtained. A new correlation of drag coefficient for the bubbles covered with hydrate membrane is established. The result of experiment indicated that the rising velocity of methane bubble with hydrate membrane would increase along with the increase of equivalent diameter, while drag coefficient would decrease before increase along with the increase of equivalent diameter. Due to the influence of hydrate membrane, the rising process of methane bubble covered with hydrate membrane would be significantly different from that of pure gas bubble; compared with pure gas bubble, the methane bubble of same diameter would have lower rising velocity. Through the comparison with known correlation of drag coefficient, it is believed that the existing drag coefficient correlations are not applicable to the prediction of drag coefficient of methane bubble covered with hydrate membrane. A new correlation of drag coefficient of rising methane bubble covered with hydrate is established, such correlation has scope of prediction error within ±25%. Considering the influence of hydrate membrane, a new rising velocity model for methane bubble covered with hydrate membrane is established to calculate the drag coefficient.
Intelligent Completion or Well Intervention Robot?
Authors: Correa Nathalia Alves , Barcelos Tadeu Franca , Miura Kazuo , Mendes Jose Ricardo 
Published: November 2017

Abstract
Well interventions represent one of the main operational expenditure (OPEX) in the O&G industry, especially in offshore fields. Historically, high cost of semi submersible rigs or drillships and long time to acomplish them have restricted the offshore well interventions. Based on this, the O&G industry has developed technologies in order to perform offshore well interventions in an economically viable way. Riserless well intervention (RLWI), intelligent completion (IC) and intervention robot (IR) are relatively new technologies and recently gained importance in the O&G industry.
Therefore, this paper details the operations and values of IC, RLWI, and IR technologies. Moreover, we analyze and compare those technologies, confronting them against the known production loss problems that require well intervention.
The objective is indicating which technologies are feasiable for the future well intervention on subsea wells.
cMIST™: Novel, Compact Dehydration System for Reducing Size and Weight
Authors: Thierens Danny , Ramkumar Shwetha 
Published: November 2017

Abstract
The natural gas industry is increasingly pursuing compact and lower weight processing technology to meet the technological and economic demands of offshore, onshore, remote, and challenged gas processing. This paper describes ExxonMobil Upstream Research Company's (EMURC) new inline dehydration and separation technology meant to replace conventional TEG tower and associated separator vessels to meet pipeline dew point specifications. Compact Mass transfer and Inline Separation Technology (cMIST™) achieves this goal with significant reductions in weight, footprint and cost.
The results of a field demonstration completed in February 2016 are discussed to establish the effectiveness and advantages of this novel technology. The technology was demonstrated using a skid-mounted unit in the Woodford trend area of Oklahoma, USA at an XTO Energy production facility. cMIST™ was tested under a range of field conditions (temperature, gas and solvent flow rates, process configurations, transient and upset) to examine the dehydration capacity, operability, and reliability.
cMIST™ relies on state-of-the-art technological advances in contacting and inline separation to achieve pipeline specification dry gas. The technology is highly modular to allow for simple transportation into remote, challenged, or offshore environments and provide installation configuration flexibility. Case studies show a 50 % weight reduction of the absorption equipment in selected applications. During EMURC's field demonstration and qualification program, cMIST™ achieved pipeline specification over a range of process conditions and during sustained operation. cMIST™ was demonstrated to have a broad application in gas dehydration.
Acid Soluble Drilling Fluids: Development and Field Trial
Authors: Wagle Vikrant , Al-Yami Abdullah S. , Al-Bahrani Hussain , AlSafran Ali 
Published: November 2017

Abstract
Stuck pipe can not only significantly increase the cost of drilling but also has the potential to decrease the chances of successfully drilling a well within the stipulated time. A number of techniques and tools have been developed to solve the stuck pipe problem after they occur. However, the real objective should be to avoid the problem of stuck pipe to begin with and if and when they occur, the choice of treatment to release a stuck pipe should be such that it is not only cost effective but also quick. Such an objective prompted us to develop a new drilling fluid formulated with a combination of two different weighting agents, viz. barite and manganese tetroxide (Mn3O4).
This paper describes the formulation of medium and high-density drilling fluids viz. 120 pcf and 150 pcf density fluids. These drilling fluids have been formulated with a combination of barite and Mn3O4 as weighting materials and hot rolled at 250°F and 300°F, respectively. After hot rolling these fluids at the specified temperatures, rheological properties and high temperature, high pressure (HTHP) fluid loss were measured. Sag resistance of the drilling fluids was estimated by perfoming static aging experiments in which the fluids were aged in inclined and vertical positions. To evaluate the filter-cake breaking potential of these mangansese tetroxide based drilling fluids, different breaker fluids were tested on the new 100pcf drilling fluid so as to calculate the % filter-cake removal efficiency. The paper also describes the data obtained from the field trial of 100 pcf and 145 pcf fluids formulated with barite and Mn3O4 for wells with a BHST of 290°F.
The paper discusses the benefits of using drilling fluids formulated with barite and manganese tetroxide in mitigating stuck pipe issues and highlights their benefits in terms of better barite sag resistance and lower equivalent circulating density as compared to conventional drilling fluids formulated with 100% barite as weighting agent. The 120 pcf fluid when static agend showed superior rheology, thin filter cake and better sag resistance as compared to the 120pcf fluid formulated with only barite as the weighting agent. Different filter-cake breaker fluids have been showon to partially dissolve the filter cake of drilling fluids formulated with the acid-soluble manganese tetroxide as a weighting agent. This partial dissolution of filter cake is sufficient to free the pipe in the case of any stuck pipe event in the wellbore. The drilling fluids formulated with a combination of barite and manganese tetroxide showed good rheology, barite-sag resistance and resulted in successful drilling of wells having a BHST of 290°F.
Optimized RA Sourceless LWD Suite for Horizontal Well Placement and ICD Completion Design in Middle East Cretaceous Carbonate Reservoir: A Case History
Authors: Brindle F. R. , Mishra A. K. , Altaf B. A. , Aragon J. C. , Allouti A. K. , Herz U. , Bhatt P. , Soliman A. M. , Deng L. , Hassan S. , Masry H. A. 
Published: November 2017

Abstract
This paper presents the successful use of LWD NMR and LWD resistivity image log technology to meet the challenge of placing wells in a thin reservoir with lateral facies variation without the use of radioactive sources and with simultaneous data acquisition to evaluate the wells and design their downhole inflow control devices (ICDs).
A series of horizontal producer wells were planned in a thin reservoir with lateral facies variation. After drilling the wells they were completed with downhole ICDs. Optimum placement of the wells within the reservoir and data acquisition to evaluate the wells and design their completions was achieved without the use of radioactive sources, as these created an unacceptable drilling risk. Rapid and accurate processing of the data in real time and subsequent design of the ICDs was required to enable the completions to run in a timely fashion. The NMR permeability was normalized using the new calibration parameters that were developed by integrating NMR results with core data, and the same relationship has been tested in other lateral wells.
Real-time NMR total porosity played a significant part in facilitating effective geosteering and well placement without the drilling risks associated with radioactive sources. In addition, the NMR provided a porosity distribution that was used to estimate a permeability index. This index was normalized using core permeability available from offset appraisal wells. The core and NMR log data in the offset wells were combined to derive the parameters for an NMR permeability relationship. The standard volumetric analysis results and the permeability index were used for identifying reservoir flow units using crossplots of normalized flow capacity versus normalized storage capacity (modified Lorenz Plots). These results were then used to develop the parameters for the ICD completions. High resolution LWD image log data was incorporated to select the best possible sections in the wells for isolation of the ICD segments. Following completion and stimulation, multiphase PLTs were run across the ICD
compartments to evaluate the wells. These results were then compared against expectations and used in subsequent well completion designs.
The results of the wells presented show that the chosen methodology enables the successful placement and completion of horizontal wells in this reservoir. Decisions about ICD completion design can be made in a timely fashion just after the drilling phase is complete, avoiding rig downtime. This approach has become the default procedure for the field and will be used for the bulk of the remaining producer wells in the reservoir.
High-Resolution Seismic Inversion Pinpoints Ultra-Thin Shale Interbeds and Sweet Spots
Authors: Tongcui Guo , Zhaohui Xia , Hongjun Wang , Liangchao Qu , Wenguang Zhao , Ping Wang , Xiangwen Kong , Li Liu , Zhi Ma , Sansheng Zhang , Jianguo Zhao 
Published: November 2017

Abstract
The W block shale in the study area is located at the West Canada basin and belongs to the low-porosity and ultra-low permeability gas-condensate reservoirs. The sandwiched layers in the shale are extremely important for reservoir reconstruction. As the single-layer thickness of the carbonate interbeds in the W block shale is very thin and have multi-stage superposition characteristics, the use of conventional geostatistical inversion cannot effectively and accurately predict the thin sweet spots and interbeds in the shale. This article uses three-dimensional probability constraints as pre-stack geostatistical inversion to replace traditional one-dimensional and two-dimensional face constraint inversion and achieved quantitative prediction of interbeds using well logging and 3D seismic data, so that prediction outcomes fully integrates well logging, seismic data and established a set of 3D probability constraint pre-stack geostatistical inversion process for thin interbeds and sweet spots in the shale. The process mainly includes the following crucial steps: (1) Well logging evaluation of shale reservoir parameters, analysis of shale rockphysical parameters and analysis of petrophysical characteristics of shale sweet spots and carbonate interbeds from well data, in order to evaluate and use seismic data to predict the possibility of shale sweet spots and interbeds. The characteristics of shale sweet spots is low Poisson ratio, moderate Young's modulus, high total organic content (TOC) and high brittleness. The characteristics of carbonate interbeds is high Poisson ratio, high Young's modulus, low TOC and high density. (2) Pre-stack gather optimization to establish six reliable partial sub-offset seismic data volumes. (3) Application of waveform difference simulation for prediction of shale interbeds, analysis of the vertical and horizontal variation characteristics of the interbeds based on post-stack seismic data and the three-dimensional probability volume of carbonate interbeds was estabilished according to the results of seismic waveform difference simulation and well logs. (4) High resolution 3D lithologic probability constrained pre-stack geostatistical inversion are performed and effectively predicted the spatial variation characteristics of shale thin interbeds and sweet spots.
Rapid Microfluidic Analysis of Thermal Foam Stability at 250 Degrees Celsius
Authors: Bao Bo , Sanders Aaron , Ren Ginger , Haas Thomas de 
Published: November 2017

Abstract
A common issue in thermal oil recovery is that a high-permeability path in the reservoir diverts steam from reaching the bulk of the pay region. Injection of thermal foams is an effective approach to improve the oil recovery factor by increasing the effective viscosity of gas phase. Conducting conventional laboratory testing on thermal foams is time consuming, often not representative of field conditions, and delivers limited amount of data. This study will outline a novel microfluidic method for rapidly screening foaming agents at reservoir-relevant pressures and temperatures. The objective of this study is to provide operators with a tool that can rapidly screen chemical additives before conducting a field pilot.
Microfluidics is the study of fluid-flow at the micro-scale (typically tens to hundreds of microns). For measurement and analysis of fluid behavior and properties, microfluidics shows unique advantages including i) fast heat and mass transfer; ii) small amount of sample consumption; iii) full-factorial multiplexed analysis. In this study, microfluidic devices are fabricated from glass and silicon wafers in a clean-room environment. A network of microscopic channels etched in the silicon wafer emulates flow through the reservoir and allows reservoir engineers to visualize the foaming process and quantify foam stability under a variety of conditions. The microfluidic device has two parallel porous media sections with two permeabilities, which allows the comparison of foam velocity.
The results of this study show that recently developed high molecular weight sulfonates, can form stable foams at 250°C. This study provides the first micro-confined visual data showing the stability of thermal foams at high-temperature and -pressure. A key observation is that the mechanism responsible for increasing the pressure-drop across a porous media may not always be the formation of foam. Some chemicals showed that deposits form in the chip and increase the pressure drop. This is proof that selecting the correct chemistry is critical to preventing reservoir damage. The speed at which the foam moves through the two porous media sections is an indication of the foam's ability to increase resistance in the reservoir.
This study demonstrates a novel approach to screening thermal foams and describes the pore-scale mechanism of foam degradation at temperature. This is the first study showing visual evidence of how thermal foams perform at reservoir-relevant temperatures and pressures (250°C and 5 MPa).
Research and Application of High-Temperature Drilling Fluid for Scientific Core Drilling Project
Authors: Wenlong Zheng , Xiaoming Wu , Yuming Huang , Jie Xu , Wenshi Wang 
Published: November 2017

Abstract
SK-2 Well is the main hole of China Continental Scientific Drilling Project in Songliao Basin, which was designed to penetrate through Cretaceous strata and recover a nearly complete Cretaceous terrestrial sedimentary record. Continuous coring was conducted from 2840m to 4542.24m in 311.2mm diameter with bottom hole temperature of 180°C during 10 months. The risk of sticking and collapse was very high in complicate formations, such as brittle shales and sandstone with high permeability. Design of high-temperature drilling fluid suitable for core drilling in SK-2 Well was of great importance and was in urgent practical demand.
Attapulgite was compounded with sodium bentonite to improve the bentonite quantity limit in formulating high-temperature drilling fluid, and additives of great salt resistance and thermal stability were optimized. Besides, different plugging agents were used to enhance the plugging efficiency and improve the mud cake quality. Based on XRD analysis of mineral compositions, shales hot aging recovery tests and cuttings contaminations tests, etc., a new type of polysulfonated drilling fluid system was formulated with improved rheological properties, plugging ability and inhibition.
Mud thickening rapidly after aging at 180°Cwhen the bentonite content exceeded 4%, but the rheological parameters were stable when bentonite and attapulgite addition was both 2%. Combining sized calcium carbonate with sulfonated asphalt could reduce water loss significantly, compared with the single use of them. A good inhibition effect was achieved by the synergistic effect of 7% KCL+5%polyglycols+1% polyamine.
This drilling fluid was successfully used in the 311.2mm section of the SK-2 Well, and the field application effect was remarkable during drilling process since seldom complicated conditions were encountered. Finally, 1683.17 meters long cores were recovered and the average core recovery rate was up to 98.88%.
ARC Eco-Lube - A Food Industry Waste-Based Green Lubricant
Authors: Amanullah Md , Arfaj Mohammed K. 
Published: November 2017

Abstract
Due to a perpetual source of various waste products, the food industry is a potential source of different raw materials for different industrial applications including the oil and gas industry. These waste products can be processed, treated or modified for various industrial uses to mitigate or overcome some of the technical challenges. For example, the waste vegetable oil generated by the food industry can be used to develop eco-friendly lubricants for exploration and exploitation of oil and gas resources without any detrimental impact to the surrounding environment, ecosystems and habitats. This paper describes an eco-friendly lubricant developed using waste vegetable oil generated by the food industry.
Experimental results indicate a significant reduction in the COF values of the water-based muds in the presence of the newly developed lubricant. Comparison of the COF reduction capability of the new lubricant with respect to non-environment friendly and poorly biodegradable diesel and mineral oils indicate better or similar performance for the newly developed lubricant. It also showed virtually similar performance in lab lubricity test with respect to a commercial green lubricant used by the industry and thus demonstrates its suitability as an alternative to commercial green lubricants. As the lubricant has been developed using a locally available food industry waste product, it will play a positive role in the growth of the local industries and enterprises. The localization of the lubricant development will create new employment opportunities for the local communities. Moreover, it will contribute in the growth of local and national economy and also in lifting the social and economic condition of the local communities.
Incorporation of the lubricant in water-based mud will reduce the COF values significantly without any change to the environmental characteristics of water-based muds. Hence, it can be used in mitigating the torque and drag problem while drilling in sensitive environments such as offshore and deep water drilling environments.
Employing Data Visualization of Reservoir Data for Better Understanding of a Mature Field
Authors: Madathil Asok , George Bina , Dangin Thibaut 
Published: November 2017

Abstract
Total has been producing oil and gas from a series of heterogeneous reservoirs offshore Abu Dhabi since 1974. This field has achieved the highest recovery factor in the region. The world class recovery factor achieved in this field was due to early application of new technologies such as ESPs, gas-lift, multi-lateral wells, field-wide tracer and state-of-the-art reservoir monitoring and well management. It is critical that the high volume of data collected from the reservoir be utilized to the maximum to better understand the field as well as to further enhance its potential.
High volume of reservoir data collected throughout the life of the mature field including saturation data, pressure data, production tests are sometimes underutilized due to lack of effective and convenient method to analyze them. By analyzing these different sources of data in a single platform, we can unlock further secrets of the reservoir which otherwise would have been unexplainable or lost. Moreover, visually representing them with proper emphasis given to type of well, time of acquisition, layers of production etc in a convenient way provides the Engineer the tool to better understand the field.
By visual representation of data the Reservoir Engineer is able to perform a Dynamic Data Synthesis of the reservoir much faster and is able to convey his findings in a much simpler way. This aids in quality checking of acquired data, early anomaly detection, and detection of reservoir trends. Using these commercial data visualization software provides the necessary freedom and ease to link data from multiple sources, present it online, share workspace and is also cost effective as it is not industry specific.
This paper will describe the practical experience implementing this commercial Data visualization software in a mature field and give example of innovative ways data from different sources were analyzed in one platform to explain the Reservoir behavior as well was some individual well performances. The paper proposes how Reservoir Engineers of the future would be dealing with big field data in day to day basis for its maximum utilization.