bluuebunny/crossref_metadata_2025_split huggingface dataset:
Gas to Wire With Carbon Capture & Storage: A Sustainable Way for On-Site Power Generation by Produced Gas
Authors: Andrei Maria , Sammarco Giuseppe 
Published: November 2017

Abstract
Natural gas has the potential to play an important role as a "bridge" fuel in the transition from fossil fuels towards a cleaner energy mix and a low-carbon future, due to its better environmental credentials (lower emissions of CO2 and other pollutants per MWh) and higher efficiency in power generation, compared to oil and coal. Natural gas is also suitable as a back-up fuel for complying with renewables and could turn in to a "final destination" fuel if Carbon Capture & Storage (CCS) technology would be competitive and conveniently located.
Natural gas with CCS could be a cheap and reliable low-carbon energy source in the long term and a critical technology for climate change mitigation, while delivering sustainable power.
Currently, the destination of most of the transported gas is as fuel for power generation, but the electricity can be generated anywhere, even at or near the reservoir source.
Gas-to-Wire (GtW) is the process of generating electricity from natural gas at or in proximity of the field, a different approach than producing electricity at a centralized power plant. In the Gas-to-Wire process a gas motor (usually a gas turbine) is placed close to the field and the gas is directly converted into electricity for own use or for sale to the local market (eventually transported by cables to the destination). For a more sustainable process, the CO2 produced by the power plant could be captured and injected underground (in a water layer or a depleted reservoir, if available in the area). Thus, the costs for CO2 transport and storage are reduced and NIMBY (Not In My Back Yard) reactions are limited, as everything remains confined inside the field and the only output is electricity.
Following this approach, the paper reports the results of a pre-feasibility study carried out applying the integrated GtW-CCS scheme to a gas production field. Economic sensitivities were performed determining the Levelized Cost Of Electricity (LCOE) and the CO2 captured cost as a function of: gas flow rate, power transmission distance and feedstock valorization.
Our analysis evidenced that the GtW-CCS scheme can be competitive in some circumstances, for instance: in remote assets (for own power), when associated gas is present and when wire transmission lines are located nearby the field. LCOE increases when capture plant is present and is particularly sensitive to location and feedstock cost.
3D SRME and Interbed Multiple Attenuation on Fully Regularized Common Offset Vector COV WAZ Data from Kuwait Single Sensor Survey
Authors: Jahdhami Moosa Al , Maag Jan Willem , Mueller Alexander , Narhari Srinivasa Rao , Kolawole Olusegun , Kidambi Vijaya Kumar , Al-Qadeeri Bashar , Dashti Qasem 
Published: November 2017

Abstract
Seismic data in Raudhatain field in Kuwait is strongly contaminated with multiples that impair the image of reservoir reflectors and challenge the structural as well as the quantitative interpretation. A reliable reservoir interpretation depends on an optimal attenuation of multiples (free surface and interbed). In this project, we demonstrated that a significant amount of multiple energy was attenuated by implementing 3D SRME together with data and model driven interbed de-multiple using two strong shallow reflectors as the dominant multiple generators.
The project was run with a primary objective of a successful multiple attenuation at the Jurassic level. Initially, 3D Fourier interpolation was applied to regularize and infill shots and receiver independently, to prepare the data for 3D multiple attenuation. However, the survey in some areas was undershot due to agricultural activities, resulting in massive data gaps which presented challenges for data regularization/interpolation.
Since the 3D data interpolation results demonstrated that this approach was suboptimal and inadequate to infill all data gaps, especially the large ones, a new strategy of incorporating legacy data (from the same area), was followed to infill these gaps in a more appropriate way.
The 3D merged dataset (vintage and new data) was used as input for 5D interpolation software which regularizes and infills the data in 5D senses producing fully regular Common Offset Vector (COV). The 5D interpolated COV panels show a significant improvement to the 3D interpolation results. With the incorporation of vintage data and implementation of 5D interpolation, the multiple predictions were improved.
After applying 3D SREM on the data, 3D interbed demultiple was implemented assuming that the dominant multiple periodicity at the target level is related to two shallow reflectors which have approximately 138ms TWT separation. As the real shallow data was too poor to use, full waveform inversion velocities were used to model the reflectivity of the shallow overburden, which used as input for 3D interbed multiples prediction together with the actual data. This 3D data and model driven approach successfully predicted the 1st order interbed multiples bouncing between these two reflectors.
This advanced 3D de-multiple approach has significantly attenuated multiples at target level allowing more reliable interpretation of the reservoir sections. Robust data interpolation and optimal implementation of novel multiple attenuation techniques were the key elements to the success of this project. Following the same processing approach on surveys or data with similar issues and challenges will help to address the seismic multiples and improve the reliability and accuracy of reservoir interpretation.
A Method for Quantifying Reservoir Connectivity Combining Reservoir Simulation and Production Data
Authors: Li Yanjing , Wei Xiaodong , Wu Ruikun , Tian Wenyuan , Chen Xin , Yan Xiaohuan , Zhong Weixiang , Yaliang Xia , Jin'e Chen 
Published: November 2017

Abstract
Static methods are commonly used to analyze the reservoir connectivity. However, the results are dubious. In this paper, an integrated method for validating results is proposed by using dynamic data and reservoir simulation. Static methods used to analyze the reservoir connectivity include seismic inversion, well to well correlations, pressure gradient, oil-water contacts, fluid property and so on. However, the study results by static data are dubious. In order to validate and improve the understanding of reservoir connectivity, dynamic data and reservoir simulation was used. First, the reservoir connectivity was investigated with the static methods mentioned above. Second, the static model was built on the basis of the geology integrated study result. Third, by combining both results stated above, a dynamic model was established. Finally, the understanding of reservoir connectivity was reasonably and effectively improved by conducting the production history matching and adjusting the static parameters. During this process, first, an unreasonable understanding on reservoir connectivity was recognized; then, a modified and improved static model was updated for the simulated results better matching production data, where the reservoirs connectivity was also updated.
Reservoir connectivity was successfully characterized with the proposed method in application field in Iraq. Results show that (1) reservoir connectivity characterization by static methods only is often not correct for local area in case field, which is validated by the simulated WTHP of some wells much lower than the actual measured data; and (2) an updated reservoir connectivity is more correct and reliable, which can improve the matching between reservoir simulation results and production data. Dynamic data and reservoir simulation is a effective method to study the reservoir connectivity incorporated with static methods. The integrated method should be trend for the reservoir connectivity characterization.
Pipeline Blockage Location by Pressure Wave Analysis
Authors: Stewart Neil , Jack Graham 
Published: November 2017

Abstract
The location of pipeline blockages continues to be a challenge to pipeline operators at exactly the moment when fast and accurate location of such blockages is fundamental to getting pipelines back in service. Methods currently exist for blockage locations; however, they are generally limited to the conditions in which they can be used or by their accuracy.
This paper discusses a new method for pipeline blockage detection using pressure wave analysis that analyzes the reflections generated by a pressure wave traversing the pipeline to the blockage location and back again. By connecting an ultra high-speed data logger to the pipeline, a pressure wave, generated by the rapid opening and closing of a bleed valve, can be recorded for analysis. The details of the pipeline and the fluid provided by the operator can be used to calculate the system acoustic velocity and, in combination with the recorded data, can, therefore, calculate the distance from the recording location to the blockage.
It can be shown that the theory behind the method is backed by results observed when using it to locate actual blockages within actual pipelines. Case studies are presented to show that the method can be used in both flowing and nonflowing pipelines, both on and offshore, in all fluids to identify where a blockage is located. The theoretical method for calculation of acoustic velocity for known system and fluid parameters can be shown to be accurate within tolerances when compared to the acoustic velocity gained in the field by recording the time of flight between two known points. It can be observed that blockages can be detected to a level of accuracy of up to 0.3% of pipeline length verified by comparison with pipeline features and with odometer data from a stuck intelligent pig.
The method presented in this paper differentiates itself from other pipeline blockage location systems by the use of pressure wave analysis. It has a higher level of accuracy than that claimed by other remote nonintrusive technologies available, therefore, giving pipeline operators the opportunity to target remediation work in a more efficient and cost-effective manner.
High Resolution Data Integration Aid on Achieving Successful Level-4 Multilateral Wells in Clastic Reservoirs of Minagish Field, West Kuwait
Authors: El Gezeery Taher , Al Shemali Nasser , Ebaid Adel , Kumar Jeevan , Padhy Girija , Das Om , Al Rashidi Tahani , Nugroho Cahyo , Pazos Jhonatan H , Noueihed Rabie S 
Published: November 2017

Abstract
The Middle Cretaceous Burgan reservoir in Minagish Field exhibits variable depositional clastic settings ranging from "Fluvial", "Fluvio-tidaT to "tidal wave sands". The sand bodies of Upper Burgan reservoir are highly heterogeneous in terms of the stratigraphic architecture implying extensive lateral facies variations, stacked sand bodies and varying petrophysical properties. Modeling the target sand channels and optimizing subsurface well trajectory with maximum reservoir contact requires "high resolution" geological and seismic data integration in order to minimize uncertainties related to correlations of timeline surfaces, channels geometries and sub-seismic fault network.
Since traditional logs could not capture the textural differences characterizing the reservoir zones, Real-time formation evaluation and geosteering challenges addressed to ensure the successful drilling and completion of level-4 "Multi-lateral" producers. A combination of the latest advanced geo-steering technology used in this well including Rotary Steerable, Distance to Boundary and Sourceless petrophysical evaluation while drilling.
The uncertainties in the geostatistical models were further reduced while drilling the first lateral section (LAT-0) by deploying extra deep azimuthal resistivity measurements. It has a higher precision and accuracy to consistently mapping the rise in OWC due to production operations with depth of detection up to 100 feet TVD above and below the well path and maintaining a standoff from the top of onset transgression undulating surface with poor sand facies.
The resultant mapping window provided accurate guides to update the geo-models. The formation evaluation along with borehole imaging and geo-correlation assisted in identifying a fault having a great impact on well positioning of the upper lateral due to a high amount of throw fault with significant formation dip changes. This is in turn eliminating risks of geosteering in such a complex heterogeneous reservoir.
The integrated approach utilizing geological, seismic, petrophysical and geosteering data provided better understanding for well positioning while drilling and achieving the MRC without exiting the sweet zones of targeted upper and lower Burgan sandstone in Minagish field and enhanced water free oil production.
Improved Reservoir Characterization in Complex Gas Carbonate Field in the North of the Sultanate of Oman
Authors: Al-Amri Mazin , Lukmanov Rinat , Al-Barwani Mohammed 
Published: November 2017

Abstract
Field N is a complex oil and gas field in the north of the Sultanate of Oman producing from several reservoirs. In this paper, the focus will be on Shuaiba gas reservoir, which is characterized by large variations in rock properties. An additional challenge is limited core data available and big gas effect observed from the logs. The described work was undertaken as part of an FDP update.
Gas correction effect and permeability modeling in such complex carbonate reservoir with the limited availability of representative core data is challenging. The density and neutron logs are affected by the presence of gas, which required advanced correction methods. The 1st applied technique of porosity correction comprised an iterative method of density and micro resistivity with simultaneous solution for residual gas saturation and corrected porosity. In addition, a new modification of gas correction was tried from Density-Neutron gas separation along with known PVT parameters was used for porosity calculation and gas corrections.
The log response of the Shuaiba reservoir in Field N looks like a classical illustration of gradual change of saturation from water leg to the transition zone and gas leg. However, flank well has been perforated close to the anticipated contact and produced gas for more than 200 days without water. As a result of comprehensive data analysis, a significant vertical heterogeneity of the reservoir was established. It was found that Gas saturation is a good indicator of permeability. A good relationship between fluid mobility from Wireline Formation Test data and water saturation from logs for gas leg was established. In the gas leg, all water is considered as irreducible, thus this is in fact relationship between mobility and irreducible water saturation. The relationship was then calibrated to permeability using the available core. As a result of this work, significant heterogeneity of the Shuaiba reservoir was captured in case of limited core data available. The remaining gas quantified for optimizing future development.
As part of this Study, an advanced gas correction method was applied resulting in more reliable Porosity evaluation. Besides, a new modification of the method for gas corrections from Density-Neutron separation was tested and showed good results.
Wellbore Trajectory Quality Management: A Key Approach to Safe Casing & Completion Strings Deployment in Complex Wells
Authors: Nobbs B. , Dao N. H. , Mollaret B. 
Published: November 2017

Abstract
Wellbore trajectory quality management is a key factor while deploying casing and completion strings. Depending on the type of directional drilling driving system, formation drilled, bit steerability and operational procedures, the trajectory can be smooth or very tortuous with significant additional local doglegs. In addition, when the wellbore surveying program is not sufficiently consistent (i.e. wellbore surveys with inadequate MWD survey sampling or Stationary Gyro surveying mode with a low sampling rate), the doglegs can be hidden and become potential difficulties down the track, resulting in ‘traps set open' for tubular running operations.
This paper presents a trajectory quality management methodology that enables the anticipation of stuck pipe problems or lock up situations when running casing and/or completion strings. This methodology involves different processes that permit the evaluation of: intermediate doglegs and wellbore tortuosityprecise casing positioning through the wellbore accounting for centralisation programtubular post buckling analysis
Robust 3D directional drilling models coupled with 3D stiff string T&D calculations (enhanced tubular string mechanics analysis) and adequate field data management are the key features of this successful approach.
Sweet Spot Mapping in the Montney Tight Gas Reservoir
Authors: Kato A. , Akihisa K. , Knapp L. , de Groot M. , Yamazaki K. 
Published: November 2017

Abstract
A common goal in unconventional plays is to create a sweet spot map by integrating all available data, including seismic data. This map could be utilized to optimize future drilling locations. Thus, in order to establish the workflow, we conducted a sweet spot mapping study in the Lower Triassic Montney tight gas play in the Western Canadian Sedimentary Basin, specifically focusing on prediction of lateral variations in condensate-gas ratio (CGR). A 3D geomodel was first created to obtain the 3D distribution of reservoir quality and completion quality properties which are expected to be potentially correlated with CGR. In the model, simultaneous AVO (Amplitude Variation with Offset) inversion results were fully utilized by geostatistically integrating with the well log data. Typical SRV (Stimulated Reservoir Volume) geometry in the study area was estimated from analysis using production data and microseismic data. For each producing well, average values for the reservoir quality and completion quality properties within the estimated SRV were obtained from the 3D geomodel to directly compare with the CGR value. Statistical analysis including crossplot and multiple-regression analysis was conducted to investigate the effectiveness of model properties as predictors of CGR. The analysis result implied that the reservoir depth and gas content are the most dominant properties for predicting lateral variations in CGR at seismic-scale. The reservoir depth is interpreted as a first-order control of thermal maturity and CGR. High gas content and low CGR is also observed in areas of higher porosity, which may correspond to secondary migration pathways for methane (Wood and Sanei, 2016); this is a second order control on gas content and CGR. Multiple-regression analysis was perfomed to obtaine a formula that explains CGR distribution by using the most effective combination of model properties. A CGR map was created by applying the established formula to the entire study area. The map of predicted CGR is consistent with the measured CGR. The map will be utilized for optimization of future drilling locations.
Assessment of Produced Water Reinjection in a Giant Carbonate Reservoir
Authors: Chen Peng , Willingham Thomas , Morrow Timothy Ian , Sowaidi Alunood K. , Stojkovic Dragan , Ning Jing , Gao Bo 
Published: November 2017

Abstract
Produced water reinjection (PWRI) is a proven field development technology which has been widely applied to numerous fields to optimize disposal of produced fluids while meeting reservoir injection requirements. However, PWRI has not been evaluated in many of the giant carbonate reservoirs which are relatively immature in the Middle East. In this paper, an on-going assessment of potential PWRI for a giant offshore field is presented.
The giant offshore oil field in the Middle East has been extensively developed since the 1970's. Seawater injection has been applied in the field since the 1980's and the produced water is disposed of through dedicated wells. The daily water production rate from this field has been increasing over time, and the continuous addition of oil producers and water injectors to capture the field reserves will further accelerate water production. Developing the most cost-effective solution to handle the significant volumes of produced water is crucial to ensure long-term operability of facilities and continued field production. A strategy to derive value from the produced water, which otherwise is considered unwanted, is to utilize PWRI. Proper laboratory assessment to determine specifications for PWRI will ensure the re-injected produced water is compatible with the reservoir fluids and that the target injection rate can be sustained through matrix flow.
The lab assessment to determine produced water quality specifications include an evaluation of the inorganic scaling potential of PWRI (fluid compatibility) and an analysis of the impact of oil carry over in the presence of fine particles on near wellbore injectivity. Thermodynamic modeling and bottle tests were performed to determine compatibility of PWRI with reservoir fluids (i.e. scale precipitation) and core flood tests at residual oil saturation with multiple rock types were completed to quantify the impact of oil carry over on PWRI specifications.
Thermodynamic modeling and bottle tests show PWRI has a lower inorganic scaling tendency than conventional sea water injection, and that scaling does not appear to be aggravated by PWRI. Core flood experiments indicate injectivity is maintained under anticipated oil carry over conditions (including upset conditions) across the various rock types evaluated suggesting PWRI may be an attractive technology to mitigate produced water disposal requirements while also meeting a portion of future field-level injectivity demand.
Using Aluminum Drill Pipe with Axial Oscillation Tools to Significantly Improve Drilling Performance
Authors: Mills K. , Menand S. , Grissom R. 
Published: November 2017

Abstract
Aluminum drill pipe has already been proven as a viable alternative to steel drill pipe when drilling long horizontal wells thanks to its lighter weight that does not compromise resistance to yield and buckling. At the same time, the development of unconventional wells has seen the deployment of numerous technologies to further improve the performance and increase the lateral section to reduce costs. An operator has recently and successfully tested a new aluminum drill pipe with an axial oscillation tool to push further the limits of the drilling system.
This paper presents the key findings of the case study using a mixed aluminum-steel string combined with an axial oscillation tool. First, the innovative drill pipe design is presented, followed by lessons learned during rig operations regarding pipe handling practices, rig compatibility and pipe inspection. Then, results of the drilling simulations performed during the well planning phase are presented. This modeling led to an optimum drill string design associating the steerable mud motor assembly, aluminum drill pipe, axial oscillation tool and steel drill pipe. The number and placement of aluminum drill pipe along the string was key to reducing friction and improving weight transfer between the bit and the axial oscillation tool.
Through extensive modeling and field data interpretation, this paper presents the comparison of the overall drilling performance between steel only and aluminum-steel drill pipe strings, and provides metrics in terms of weight transfer and rate of penetration improvement. This innovative and promising drill string design opens the doors to set new limits in terms of horizontal departure.