bluuebunny/crossref_metadata_2025_split huggingface dataset:
Critical Factors Affecting Pulsed Neutron Saturation Monitoring in Carbonate Reservoirs
Authors: Eltaher Yahia , Ma Shouxiang , AlNasser Mamdouh 
Published: October 2018

Abstract
Pulsed neutron spectral carbon/oxygen (C/O) logging is a widely used shallow measurement for time lapse reservoir saturation monitoring. Because of its shallow depth of investigation, its measurement is affected by several factors among which the near wellbore logging environment is the most important. For example, hole condition, cement quality and fluids in the wellbore have drastic effects on C/O measurement. Some of these effects, such as those due to oil holdup in the wellbore, can be corrected for in the data post-processing. Others might have a permanent imprint on the data, which cannot be removed. It is therefore extremely important to fully understand the effects of the different physical parameters within the wellbore vicinity that might be affecting the measurements.
An extensive study was conducted in a field where reservoir saturation monitoring logs encountered discrepancies in water saturation between open hole and C/O logs, where the latter showed changes in saturation not supported by production history. It was found that one of the main reasons behind this discrepancy is the effect of mud filtrate invasion on the shallow C/O measurement, which varies as a function of timeand rock type characteristics. Other factors, such as wellbore fluid reinvasion effect across zones of perforation, also play a role.
In this paper, it is demonstrated with field examples the effect of mud filtrate on C/O logs and define criteria used to diagnose this phenomenon. It is also highlighted other factors affecting C/O measurement such as wellbore fluid reinvasion and cement condition. Last, we present recommendations and best practices to conduct a more representative reservoir saturation monitoring.
New, Integrated Approach to Diagnose, Characterize and Locate Inter-Well Fracture Connectivity in Carbonate Reservoirs From Transient-Test Data
Authors: Al-Obathani Omar H. , Al-Wehaibi Bandar A. , Al-Thawad Faisal M. , Rahman N. M. 
Published: October 2018

Abstract
Characterization of natural fractures in carbonate reservoirs to the resolution of well tests is reliable for major fracture corridors. These fracture corridors, intersecting or non-intersecting the wells, impact the well performance and the ultimate recovery in the field. Good transient-test data is the key to diagnosing fractures and their characteristics. When fractures exist between the wells, it requires some additional efforts in locating these with respect to the wells.
To overcome this challenge we propose a new approach of building 3D, numerical models to diagnose and characterize the inter-well fracture corridors. In addition, these 3D multi-well, numerical models are to determine the location and the extent of fracture corridors by utilizing dynamic pressure-transient data. The innovative idea of bringing multiple wells to the models to consider interference of wells and fracture corridors makes the models robust.
We have been able to identify the inter-well fracture corridors successfully in carbonate reservoirs by performing pressure-transient analyses on wells. By adjusting the inter-well locations of fracture corridors and the extents of these fracture corridors in the multi-well models, we try to achieve the best possible matches with the transient-pressure data. This integrated approach will provide essential input to 3D full- field reservoir models, and will lead to optimizing field management.
Maximizing Asset Value in a Mature Field Using Logging While Drilling Solutions: A Case Study, Onshore Oman
Authors: Al Jahwari Mohammed , Abdulkarim Anar , Aki Ahmet , Al Ajmi Najeeb 
Published: October 2018

Abstract
Enhanced reservoir understanding is critical for the development program of a mature field. This understanding will optimize petrophysical data gathering requirements, wells construction costs, and overall reservoir management strategy to maximize the asset value.
Logging while drilling (LWD) technologies were used in multiple wells to provide an integrated petrophysical and geomechanical interpretation. The bottomhole assembly (BHA) included LWD gamma ray, resistivity, bulk density, thermal neutron, acoustic, high-resolution imaging, and formation pressure sensors. A deterministic multimineral petrophysical model was used for formation volumetrics and fluid analysis.
Geomechanical interpretation used high-resolution microresistivity imaging and acoustic slownesses together with caliper data.
Historical data were also evaluated to determine sweep efficiency and residual fluid saturations.
LWD sensors have proven to provide robust geological, petrophysical, and geomechanical data, as compared to previous traditional wireline data acquisition.
High-resolution images facilitated fracture evaluation and the determination of the reservoir facies, leading to the identification of flow units.
Integrated interpretation has enabled the identification of the completion intervals. Well test results and the production profiles facilitated the reevaluation of the petrophysical cutoffs for the calculation of the oil in place and remaining oil saturations. Reservoir petrophysical attributes were updated in correlation with other data, including the identified pressure depletion intervals honoring history matching.
The interpreted results, based on LWD data, have facilitated the benchmarking of future data- gathering requirements to optimize the overall reservoir management strategies.
This pilot case study prompted a feasibility study to evaluate various well construction and completion design options, including high-angle and horizontal wells, for the future development program.
Development and Application of an Artificial-Neural-Network Based Expert System for Screening and Optimization of Polymer Flooding Projects
Authors: Sun Qian , Ertekin Turgay 
Published: October 2018

Abstract
Polymer flooding is one of the most broadly implemented chemical EOR processes due to its low injection cost and its success in prolific production increments. This work develops an artificial-neural- network based expert system by utilizing numerically generated training data using a high-fidelity numerical simulation model. Injection-pattern-based reservoir models are structured to establish the knowledge-base that serves for the ANN training. The injection process starts with water injection and switches to polymer injection when the water cut reaches to a threshold value. The chase-water is followed after a prescribed amount of polymer slug is injected. The expert system is generalized in terms of reservoir rock and fluid properties, rheological properties of the polymer solution, and critical engineering parameters to adjust to the complexities exhibited in the polymer injection projects. In developing the inverse model for project screening and design purposes, we have used an engineering design protocol employing inverse and forward-looking expert systems with the goal of exploiting the non-unique nature of the inverse problems. In this work, we employ the expert system as a forecasting and screening tool that is capable to predict time series based response in terms of oil production, water production and injection well sandface pressure data. The validity of the forward-looking expert system is confirmed via extensive blind test applications within a 5.83% error margin. More importantly, we present a project screening protocol that couples the expert system and particle swarm optimization (PSO ) methodology to maximize the net present value (NPV ) of polymer injection projects. In this way, we take the advantages of the fast computational speed of the ANN model to evaluate the finesses of project parameters. In the application of the inverse expert system, we observe that the proposed design protocol is capable to establish a catalogue of polymer injection design parameters that satisfy an expected hydrocarbon recovery performance. The work described in this paper exhibits the robust nature of the proposed expert system in adapting to strong non-linearities encountered in the polymer flooding projects. The coupled utilization of the inverse and forward-looking modules, enables the design engineers to find solutions that are unique to the problem being studied by simultaneously satisfying the imposed constraints effectively. The expert system proposed in this paper is one of the modules of a comprehensive artificial-neural- network based toolbox that includes a large spectrum of EOR processes.
Consequence of Graphene Oxide Nanoparticles on Heavy Oil Recovery
Authors: Elshawaf Mohamed 
Published: October 2018

Abstract
Heavy oil reservoirs embrace 70% of worldwide oil reserves. A lot of challenges face such oil production like its large viscosity which can be reduced under the action of aquathermolysis reaction. Aquathermolysis reaction is the main objective used to analysis and explain the effect of nanoparticles addition on heavy oil. Several thermal recovery techniques have been implemented using different nanometals for recovery improvement of heavy oil reservoirs and viscosity reduction.
These published trials focused on nanometals but none of them addressed usage of Graphene oxide nanoparticles for such improvement of heavy oil recovery, and therefore this paper represents an experimental investigation of graphene oxide effect on heavy oil production. The present work examines graphene oxide nanoparticle in heavy oil viscosity since graphene is a superlative material that has an extraordinary thermal conductivity up to ten times value of any nanometal. In order to check its efficiency for Heavy oil recovery, several published scenarios have been executed on light oil which leads to recovery reaches 12.5 %.
In our work, the concentration used for these nanoparticles is ranging from 0.01: 0.5 wt. %. The viscosity of these nanoparticles with heavy oil sample has been measured to explain the expected improvement in recovery factor. The Experimental work showed a large change in the viscosity after using nano Graphene oxide reached to 40:60% reduction in its original values. In addition to the viscosity, the effect of reservoir temperature is investigated. The range of temperature used in this study varies between 40° to 100° C. These results reflect strong indications for better viscosity reduction. Therefore, better recovery factor for this heavy oil.
Meanwhile, this present research provides an investigation of aquathermolysis reaction for such materials which is the main reason for heavy oil viscosity reduction, also it represents Graphene Oxide as new nanoparticles for improving Heavy Oil Recovery that will create a new era in thermal recovery for heavy oil. Also, an economic study is investigated.
Post Frac Proppant Clean Out While Testing
Authors: Nassef Amr , Al-Basha Hussain , Al-Qahtani Nasser 
Published: October 2018

Abstract
Conventionally, after a well has been fracked using proppant, wells are flowed back to clean using SMS (Sand Management Systems) equipment. Only after proppant levels go to a minimum, the flow is diverted to the testing Equipment and the well gets tested. This paper proposes an alternative approach where operating companies are given the opportunity to continuously monitor the well behavior and its production potential through well testing that takes place simultaneously during the cleanup and proppant disposal. It also proposes a solution to reduce or even eliminate flaring during the clean-up process.
Flowing wells with high solid content has always created the risk of wash outs due to the high erosion it creates. The risk of erosion is way higher during post frack clean up where proppant travels with gas at extreme velocities. Well Testing companies use SMS equipment to control and knock out solid contents in the flow. Usually, the flow is directed to the flare until the well is clean & proppant free to avoid any erosion to the well testing equipment and the production line. The proposed approach includes utilizing five different types of SMS equipment, rigged up in series to secure a proppant free fluid flowing downstream. The system consists of a Sand Catcher, Sand Filter, Sand Snoop, Choke, & a 4 phase separator rigged up respectively in series.
The design was tested in more than one location on high pressure gas wells in Bahrain. It was observed that Sand Catchers remove the bulk of the proppant facilitating quick and time efficient clean up. The filter however picks up the remaining solids that have managed to pass the Sand Catcher. The sand snoop gives the operators a close monitoring facility to guarantee no solids are passing this stage. The Choke controls the velocity on the upstream and reduced pressure on the downstream. The 4 phase separator however, acted as a backup plan and as a mitigation in case any solids reach this stage. Testing the well utilizing the separator was possible during the cleanup and flow easily directed to production lines without any risk of erosion to the testing equipment and to production line.
None of the technology proposed in the paper is new. However, the paper adds value to the existing body of literature by enhancing the utilization of existing technology with an almost flawless design which results in a more cost effective & environmentally friendly solution for post frac clean ups and testing.
Structure-Solubility Correlation for Asphaltene Deposit Removal
Authors: Hamzaoui Bilel , Al Moajil Abdullah M. , Ghamdi Abdulaziz Al 
Published: October 2018

Abstract
Several types of fluids are used to remove the heavy organic deposits precipitated along the wellbore, the gravel pack, the screen, or other equipment for processing the subterranean formation.
The effects of solvent type, temperature and additives on the solubility of the aggregated asphaltene particles were investigated. For the same solvent, the quantitative behavior of the solubility with temperature were similar, displaying an increase in the solubility at higher temperatures. To identify the effectiveness of solvent type and additives to dissolve asphaltenes, various aromatic, aliphatic, heteroatom and surfactant based solvents were used. It was found that heteroatom, surfactants and hydrogen donor compounds increased the solubility by a moderate degree, whereas aromatics increased the solubility by the highest degree. Aromatic solvents such as xylene are not faveroed during asphaltene removal treatments because of low flash point.
Creating Indigenous Technology: Utilization of Local Resources
Authors: Shaikh U. A. , Khayyat I. M. 
Published: October 2018

Abstract
Saudi Arabia is undertaking economic reforms where it is working towards reducing imports, encouraging manufacturing, and promoting the creation of localized technologies. This provides the Kingdom's private-sector with a unique opportunity for growth and expansion, in an effort to maintain relevance and maximize profits. One possible approach to achieve this is the establishment of indigenously grown research and development centers which utilize local talent and resources. Unfortunately, local talent is not necessarily at the level at which the future economy needs it to be and needs to be cultivated and nurtured with the correct methodology.
This paper outlines a strategy for the development of local talent in the course of business operations and defines the various programs and initiatives that can be executed in the private-sector. It details a framework that companies can follow to mature and develop fresh hires for work in both traditional engineering projects and product development.
Moreover, this paper describes the implementation of the aforementioned strategy and methodology by Rawabi Holding Company in an effort to not only develop innovative solutions and increase revenues, but also stimulate economic growth in Saudi Arabia's evolving environment. It analyzes the efforts taken by the company in order to develop their locally sourced talent in their established research and development group and evaluates the success of the measures taken.
In summary, this paper provides a roadmap proven in the local market for talent development which can be used by the private-sector to benefit companies in transitioning to a more development and manufacturing oriented Saudi Arabia.
A Journey Towards Building Real-Time Big Data Analytics Environment for Drilling Operations: Challenges and Lessons Learned
Authors: AlBar Abdullah H , Alotaibi Bader M , Asfoor Hasan M , Nefai Mohammad S 
Published: October 2018

Abstract
Establishing a Big Data Analytics environment for Drilling operations is impacted by many factors such as the nature of drilling operations that requires quick decision making and has a diversity of data sources. This paper goes over the process of building a Real-Time Big Data Analytics environment and highlights key learning and challenges from this endeavor.
The process of building such an environment is multifaceted. It involves building a Big Data solution architecture capable of handling the expected workload which includes servers, network, and software architecture. In addition, it requires establishing a data engineering pipeline that enables combining drilling data sets coming from different sources, reformatting and optimizing it to simplify and speed-up analytics.
The data engineering pipeline is used to tackle different drilling data types which include a master structured database that describes the drilling planning, configurations, and operations, real-time drilling sensor data stored in WITSML semi-structured format (an E&P specific extension of XML), in addition to other unstructured content such as drilling reports.
Data quality procedures were also added to the pipeline in order to identify and handle outliers in the data. In addition, data wrangling procedures were developed to ensure that the data is in the right shape and ready for analytics and machine learning. Moreover, this drilling analytics environment was built while maintaining all business security policies and fine-grained access control rules defined on the original data sources.
The established Big Data Analytics environment results in a simpler and a shorter data science lifecycle and thus making it easy to combine, explore and deploy analytical models. This leads to more efficient business operations. Building a successful analytics environment requires much more than the technology piece. It involves many factors such as data ingestion, cleaning, wrangling while maintaining business security policies. This paper provide a unique perspective on how to build such an environment for real-time drilling operations.
Drilling Influences on Formation Breakdown in Hydraulic Fracturing
Authors: AlBahrani Hussain , Al-Yami Abdullah , Hamid Osman , Wagle Vikrant 
Published: October 2018

Abstract
The influence imposed by drilling operations on the outcome of hydraulic fracturing has been well studied in terms of the post-frac stage productivity. Drilling induced formation damage caused by drilling fluids solids and filtration invasion is routinely linked to both the design and the results of stimulation operations in general. Nonetheless, hydraulic fracturing performed on deep and tight sandstone reservoirs presents a new challenge that requires a new perspective when it comes to analyzing the link between drilling and fracturing. The tightness, depth, and highly stressed nature of these formations mean that achieving formation breakdown for the hydraulic fracture initiation is a challenge. To gain a better understanding of this challenge, the role played by drilling in influencing formation breakdown is examined using different types of drilling data pertaining to stimulated intervals.
The proposed examination is carried out by uncovering the variations in different sets of drilling data and correlating those to the results of fracturing. The sets of drilling data considered describe the drilling fluids rheology, drilling fluids interaction with the formation, and the drilled wellbore quality. These observed variations are then investigated through lab experiments where applicable. Other than lab experiments, the links between drilling influences and formation breakdown is established through either data analytics or technical evidence provided by the published literature. Upon establishing the link between drilling influences and fracturing, detailed recommendations are produced to improve the success rate of hydraulic fracturing operations in terms of formation breakdown.
As anticipated, parameters indicating the damage-ability of the fluids used to drill the stimulated intervals showed a clear link to the outcome of formation breakdown attempts. These parameters are mostly measured by the Particle Plugging Apparatus on location prior to and while drilling the intervals of interest. Recommendations to mitigate the effect of these parameters is issued based on a redesigned formulation of the drilling fluid employed. Other influences include certain drilling events that limited the burst pressure rating of the downhole tubulars (casings and liners) to a value below what is necessary to initiate a fracture.
The work presented in this paper has the potential to significantly improve the success rate of stimulation operations in deep and tight sandstone reservoirs. This is proposed to be achieved by uncovering new links between different drilling influences and the formation breakdown. Complementing the outcome of this work with the rich body of literature investigating the relationship between the post-frac stage productivity and drilling can present a new pathway to access reserves in challenging environments.
Optimizing Impressed Current for Effective and Economic Cathodic Protection of Well Casings
Authors: Sharma Hemant K. , Al-Mulhim Abdulrahman K. , Al-Mutairi Saad M. 
Published: October 2018

Abstract
Anodic corrosion is a direct contributor to external well casing leaks. For some of the exploration and production (E&P) companies, it has been effectively addressed by investing in and installing cathodic protection systems using surface DC rectifier systems that supply Impressed Current Cathodic Protection (ICCP) in wells across all oil and gas fields. Yet, casing leaks due to external corrosion remain a recurrent conundrum, and casing completions still require continual monitoring and repairs despite significant capital investment and energy expenditure.
Recommended design of efficient ICCP systems via modeling is one of the solutions for achieving optimum casing protection. The method for determining whether all anodic zones are eliminated and to ensure that too much energy is not consumed and wasted is to physically measure current flow across the entire casing length, establish flow direction, as well as authenticate the depth of maximum ICCP effectiveness through an effective monitoring program.
This paper describes multiple wells utilizing ICCP, measuring downhole current flow within casings while utilizing existing or historic surface impressed amperage. Once the direct current (DC) profile is acquired across the casings and an effective ICCP depth is established, then surface amperage is either adjusted higher to increase maximum casing protection depth or it is tuned lower to reduce amperage for the purpose of economizing power consumption. Using proper cathodic protection systems not only optimizes the amount of the cathodic current requirement but also enhances the life of the solar modules for solar photovoltaic systems or life of anodes for the ICCP. In addition to ICCP profiling and fine tuning the cathodic current, the corrosion logs for these wells are also compared with detailed analysis.