bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Data-Driven Model for Rapid Evaluation of Miscible CO2-WAG Flooding in Heterogeneous Clastic Reservoirs
Authors: Jaber Ahmed Khalil , Alhuraishawy Ali K. , AL-Bazzaz Waleed Hussien 
Published: October 2019

Abstract
The compositional flow simulation model was frequently used to evaluate the miscible water alternating CO2 flooding (CO2-WAG). The uncertainty and sensitivity analysis have to be conducted to examine the parameters mostly affecting the performance of the process. Accordingly, multiple simulation runs require to be constructed which is a time-consuming procedure and finally increase the computational cost. This paper presents a simplistic approach to assess the miscible CO2-WAG flooding in an Iraqi oilfield through developing a statistical proxy model. The Central Composite Design (CCD) was employed to build the proxy model to determine the incremental oil recovery (ΔFOE) as a function of seven reservoir and operating parameters (permeability, porosity, ratio of vertical to horizontal permeability, cyclic length, bottom hole pressure, ratio of CO2 slug size to water slug size, and CO2 slug size). In total, 81 compositional simulation runs were conducted at field-scale to establish the proxy model. The validity of the model was investigated based on statistical tools; the Root Mean Squared Error (RMSE), R-squared statistic and the adjusted R-squared statistic of 0.0095, 0.9723 and 0.9507 confirmed the reliability of the model. The most influential and the optimum values of the parameters that lead to the higher ΔFOE during miscible CO2-WAG process were identified through proxy modeling analysis. The developed model was created based on the Nahr Umr reservoir in Subba oilfield and can be applied to roughly estimate the ΔFOE during the miscible CO2-WAG process at the same geological conditions as Nahr Umr reservoir.
Data Driven Predictive Modelling Assists in Proactive Water Cut Management in a North Kuwait Heavy Oilfield
Authors: Kharghoria Arun , Alshammari Abdulrahman , Gonzalez Santiago , Sanwoolu Ayodele Olusegun , Al-Rabah Abdullah Abdul , Montero Jacobo , Gonzalez Gregorio 
Published: October 2019

AbstractThis study presents the development of predictive models (for a single or a group of wells) to proactively manage water production in a heavy oil field in North Kuwait (average 16 °API crude, ~100 cp at 100 °F). Each resulting model is based on reservoir and time-dependent wellbore mechanical parameters that were obtained through several well tests. The primary goal is to be able to predict the water cut based on a well's current as well as "possible near-future" operating conditions.The exercise involves using advanced predictive methodologies. Standard parameters (referred to as features) include water cut as the response variable along with pump intake pressure, total liquid production, pump speed, and surface unit power consumption among others as response variables. Random ForestsTM (RF), Alternating Conditional Expectations (ACE) and Multiple Linear Regression (MLR) algorithms were tested. Features were primarily grouped based on clustering. The predicted results are compared to history. The resulting models are further extended to generate type curves for future water cut prediction for different combinations of the operating parameters.MLR and ACE based predictive models showed promising results. These algorithms also provided a way to characterize the influence of different features on the model outcome (i. e. predicting historical water production). The model quality significantly improves when only time-dependent features are used. The static parameters (e.g. permeability, perforation stand-off to oil-water contact, pump size) do not appear to have a big impact on improving the model score. Also, improvements were observed by introduction of principal component analysis (PCA) followed by clustering. The generated type curves allow the prediction of the near-future water production and to proactively adjust a well's operating parameters.A predictive model is a time-saving tool compared to full range dynamic simulation. This provides a means to the engineers to establish an operating envelope for a well (or a group of wells) to manage water production. This is also a precursor to a full-scale machine learning process that could be implemented for automatically updating models when the quantity of data is expected to be massive in the coming years.
Keeping The Bucks Rolling: Monetizing Shallow Hanging Fruits Through Behind Casing Opportunities and Strategic Collaboration
Authors: Zulkipli Siti Najmi , Harun Norhana 
Published: October 2019

Abstract
Maximizing production and sustaining it as much and as long as could is the aspiration to all oil and gas key players. Current producing reservoirs may not giving good yield till the end of expected production life due to depletion and watered-out issue. Presence of prolific reservoirs with thick pay zones and excellent quality are also becoming scarcer. Hence, prior to the onset of production decline, efforts to arrest it need to be addressed strategically both in short-term and long-term basis. This paper will present several case studies on monetizing behind casing opportunities (BCO) to assist in production enhancement as well as adding value to the reserves portfolio.
Identifying BCO opportunities starts by screening the potential from several sources including idle wells, wells with declining rate less than 200 bopd and high water-cut and also wells with new unperforated reserves to be put on stream. Comparison of nearby wells performance and generating stick plots to detect fluid contact movement will be part of the screening stage. Application of in-house reservoir enhanced modeling (REM) to reveal those new promising reserves which are masked by thin lamination, low resistivity and high silt content proves to have an astounding impact in production gain which are further ranked for execution priorities. To support industrial collaboration, all high risk, high cost and complexity well candidates could be clustered under special contract arrangement where the solutions, technology and execution methods will be proposed by the service providers.
Results indicated minimum of 1489 bopd of instantaneous gain is recorded with significant new reserves addition which further open-up new opportunities for appraisal and development drilling campaign. String management has improved by 20% due to idle wells reactivation, 14.8% reduction in water-cut and even 2 years extension of well economic life. Through strategic collaboration with service companies, several new technologies are successfully unlocked to deliver the barrels at minimum 15% cost optimization with the ‘know-how’ technology being replicated to similar facet of production business across the company.
In a nutshell, BCO and strategic collaboration are two major pipelines for expanding resource base and generating the cash. The efforts must continue with more success being replicated and bringing more technology to initiate chain impact to production growth.
An Approach to Benchmark Summaries of Core Data and Procedures for North Kuwait Heavy Oil Fields, Against Similar Heavy Oil Operations in Other Countries
Authors: Saikia Pabitra , Freeman Michael , Choudhary Pradeep , Tyagi Aditya , Zhang Zhiyi Ian , Benham Philip , Warrlich Georg , Gomez Fernando , Al-Terki Abdulrazaq , Ahmad Fatma , Ahmad Khalid , Al-Wael Hamad , Taqi Fatma , Al-Boloushi Ahmad , Al-Doub Abdulaziz , Al-Rabah Abdullah 
Published: October 2019

AbstractChallenging aspects to heavy oil field development are the large volume of data which is collected, in particular from cored evaluation wells, and the difficulty in evaluating of the quality of such data. This paper outlines an approach to summarize coring data and procedures from two heavy oil fields in North Kuwait, and then to compare those summaries with similar heavy oil operations in other countries, in order assess their quality and degree of representativeness.For two North Kuwait heavy oil fields, data was tabulated for the cumulative amounts of core cut and recovered relative to their field areas. This data was then further analyzed to summarize recovery by rock type, and assess the quality and quantity of plug samples collected. Benchmarks were established by summarizing core data from similar heavy oil operations in other countries, and the North Kuwait heavy oil data was then compared with those benchmarks. In a similar manner, documented core handling procedures for North Kuwait Heavy Oil operations were compared with procedures from similar heavy oil operations in other countries.The benchmarks which were used to compare North Kuwait Heavy Oil data summaries with other countries include the following: 1) Coring Well Area Coverage Densities; 2) Coring Well Vertical Coverage of Cap Rock and Reservoir Intervals; 3) Core Plug Sample Rate and Survival Rate; and 4) Core Handling Procedures and Volume of Coring.For many of the benchmarks used, North Kuwait heavy oil operations compare favorably with similar operations from other countries. However areas of improvement were identified from these benchmarks in terms of areal core coverage, vertical core coverage, core plug rates and core handling procedures. It is expected that these improvements, when implemented, will lead to a more representative sampling of the areas and rock types (reservoir rocks, baffles and cap rocks) in North Kuwait. This in turn should lead to a better understanding of fluid volumetrics, reservoir characterization and subsequent life of field development. As well by applying a focused approach to future coring operations, a significant cost savings is expected relative to original evaluation well plans.A significant product from this study is a large summary database of all coring information for two North Kuwait heavy oil fields, which can be queried by area, rock type and sample type. This data base has been compared with similar operations in other countries using a series of benchmarks. Planned future coring and sampling operations have been modified through the use of this benchmarking tool.
Development of the Hybrid Sand Control Screen for Surface Size Exclusion and Depth Filtration Media
Authors: Hosseini Seyed Abolhassan , Roostaei Morteza , Mahmoudi Mahdi , Alkouh Ahmad , Fattahpour Vahidoddin 
Published: October 2019

Abstract
Production from weakly and unconsolidated sand formations relies on the efficiency of the employed sand control method. Performance of current sand control devices is based on surface size exclusion and depth filtration depending on their geometry and application. In this study, we investigate the possibility of using the advantage of both mechanisms in a single device.
The standard cut point test was used to determine the micron rating of different meshes in order to categorize them in different classes based on the average pore size. Different mesh weaves, namely Dutch twill, reversed Dutch twill and square mesh screens with different micron rating were investigated in terms of filtration performance. In the next step, a dead-end filtration set-up was designed and commissioned to evaluate the flow performance and sand control capabilities of mesh screens. Additionally, a new, customized sand control device was designed and included in the testing matrix to compare its performance with the common mesh screens in the market.
Dead-end filtration results indicated that by choosing the proper combination of morphology, both optimized open to flow area (OFA) and sand control could be achieved. The custom designed hybrid screen performed better compared to other investigated mesh screens with similar micron rating, in terms of both flow and filtration performance. Therefore, the customization was found to be the key parameter to achieve the optimized design. This further emphasizes that by employing the hybrid benefits of surface size exclusion and depth filtration, one can reach the optimized sand control and flow performance. Regarding the weave of different mesh screens, the results did not show any trends that could lead to a conclusion of better performance of a certain weave. Further investigations are required under different testing condition to achieve a conclusive comparison between different mesh types.
This paper investigates the possibility of customized sand control design, which uses the hybrid benefits of surface size exclusion and depth filtration to reach the optimized sand control and flow performance.
Overcoming Challenges Resulting from Surplus Fuel Oil
Authors: Al-Azmi Mohammad Falah , Ojha Gunjan 
Published: October 2019

Abstract
Reduction of LNG prices has thrown up a very serious challenge for the Refining Industry as it is rapidly replacing the demand of the Fuel Oil. Refiners need to find a way for a suitable upgrade of the Residual Fuel Oil from the Crude Distillation Units (CDU). One of the most economical and attractive ways to do this is to process the surplus Fuel Oil in the Resid Fluidized Catalytic Cracking (RFCC). These days, higher amount of surplus Fuel Oil is resulting in Higher capacity RFCCs. However, does it come without any challenges? Certainly No. As we all know that the current market scenarios discourage production of Gasoline while emphasizing on maximizing Poly Propylene and Para Xylene. However conventional RFCCs are considered for producing Gasoline. So, we are left with a challenging question. How to minimize Gasoline from RFCC while increasing its capacity? It is rarely possible to reduce Gasoline production while increasing RFCC capacity. Sounds Impossible but this is made possible by an innovative Process Unit Reconfiguration in KIPIC. This article will highlight the various challenges associated with the increased RFCC capacity. This will discuss in detail how the optimum configuration is achieved for minimizing the Gasoline production and maximizing the feed stocks to downstream Poly Propylene and Aromatics complex to produce the valuable Polypropylene and Para Xylene. The paper will conclude that by an innovative Process Unit Configuration, the overall Gasoline quantity can be reduced by 15% even by almost doubling the RFCC capacity. It will also elaborate how the optimum configuration helps in reducing the overall CAPEX / OPEX of the units, increases the overall reliability, eliminates the dependence on the imported feed stocks and helps in value maximization of the intermediate streams. The paper will be of interest to anyone who is involved in carrying out the Configuration study for the secondary processing units of the Refinery and looking for optimum solution to the surplus Fuel Oil. It will provide an insight to the latest options available for upgrading the fuel oil to various products meeting the current market demands with minimum CAPEX and OPEX. The paper also focusses on how RFCC overall Reliability is increased and how yields of high value products is maximized from the unit.
Dynamics of Surfactant Flooding in Tight Carbonate Rocks
Authors: Rabbani Harris Sajjad , Osman Yossra , Almaghrabi Ibrahim , Rahman Mohammad Azizur , Seers Thomas 
Published: October 2019

AbstractWith the global increase in the demand for crude oil, the need to develop enhanced oil recovery techniques is crucial. These techniques must focus on how to displace greater volumes of trapped oil from within a given rock. Since carbonate reservoirs constitute over half of the world's oil reserves, research has recently shifted its focus on recovery techniques as they pertain to carbonate reservoirs. However, due to complex depositional textures and diagenetic processes, carbonate reservoirs are challenging in terms of recovery. In this study, a robust experimental core flooding setup is employed to assess the impact of wettability of tight carbonate rock in governing the effectiveness of surfactant flooding. A series of flooding experiments with well-defined boundary conditions were performed on the low porosity core plug samples of Indiana Limestone. The three core samples used in this study are referred to as FD3H, FD4H, and FD5H. The cores have an approximate dimension of 13 cm length and 3.8 cm in diameter. The porosity is in the range of 13-21% and the permeability is in the of 0.69 −2.17 mD. The core samples exhibited differing wetting characteristics: strongly oil-wet, moderately oil-wet and weakly oil-wet. Initially, the core samples were saturated with oil and then water flooding was conducted until irreducible saturation was achieved. Later, surfactant flooding was performed as a tertiary recovery technique. The experimental results demonstrate that the efficiency of surfactant flooding increases as the tight carbonate rock get more oil-wet. The strongly oil-wet core manifested highest oil recovery, whereas in the weakly oil-wet core the recovery efficiency as a result of surfactant flooding was least.
Laboratory Imaging and Phase Field Modeling of the Interaction of Hydraulic Fractures with Well Cemented Natural Fractures
Authors: AlTammar Murtadha J. , Alotaibi Talal E. , Sharma Mukul M. , Landis Chad M. 
Published: October 2019

Abstract
Induced hydraulic fractures in the field interact heavily with pre-existing natural fractures in the rock that are abundant in many formations. Most laboratory fracturing investigations in the literature consider pre-existing fractures as frictional interfaces with zero thickness. However, natural fractures in subsurface formations are often sealed with mineral cementing material of finite thickness. In this study, we present a novel experimental demonstration of the behavior of an induced hydraulic fracture as it approaches a cemented natural fracture utilizing a two-dimensional (2-D) hydraulic fracturing cell.
Sheet-like test specimens are cast with natural fractures of varied mechanical properties, thickness, and relative position to a fluid injection port. Plaster is used as the specimen matrix. The filling material for hard natural fractures are cast using hydrostone while soft natural fractures are cast using a mixture of plaster and talc. Several tests are performed to characterize the mechanical and flow properties of these materials. A novel method for casting the specimen matrix and filling material of the natural fracture is described and used to enable strong bonding between the natural fracture and specimen matrix. The test specimen is placed between two thick, transparent plates and constant, anisotropic far-field stresses are applied to the specimen. Fracturing fluid is injected in the center of the specimen and the induced fracture trajectories in several experiments are captured with high-resolution digital images.
We show a clear tendency for the induced hydraulic fracture to cross thick natural fractures filled with materials softer than the host rock and to be diverted by thick natural fractures with harder filling materials. The induced hydraulic fracture also tends to cross hard natural fractures when the natural fractures are relatively thin. In addition, the induced hydraulic fracture from the injection port is shown to be diverted by a thin, hard natural fracture that is placed relatively close to the injection port but crosses the same natural fracture when placed farther away from the injection port. Using our in-house numerical simulator that is based on the phase field approach, we model these laboratory experiments to gain insights into the observed fracture behaviors.
Our results provide clear evidence of the impact of natural fracture filling material, natural fracture width, and the induced hydraulic fracture length on the outcome of hydraulic fracture interaction with natural fractures. The small-scale, 2-D nature, and well-characterized properties of our laboratory specimens are also valuable for validating numerical hydraulic fracturing simulators that are capable of modeling the effect of pre-existing natural fractures on hydraulic fracture propagation.
Secure and Resilient Digital Oil Fields in Kuwait Oil Company
Authors: Al-Shammari R.. , Al-Mai N.. , Robert H.. , Charife Tamer 
Published: October 2019

Abstract
Over the years, cybersecurity threats have grown significantly, and securing Operations Technology (OT) assets is one of the biggest challenges within the oil and gas industry today. Poor security policies could lead to unauthorized access to business-critical assets, confidential information leakage and result in business disruptions causing HSE, financial, and reputational impacts. This paper details how advanced and robust security policies shall mitigate cybersecurity risks and enable a smooth execution of Digital Oil Filed (DOF) projects and other complex O&G projects involving high convergence between IT & OT environments.
The DOF projects include integration of Industrial Control System (ICS) network with corporate network at various levels, and this mandates consideration of multiple layers of security controls to implement a defense in depth strategy in order to secure ICS & Corporate infrastructure. It includes establishment of an integrated governance model that orchestrates the Cybersecurity Management System (CSMS) that encompasses IT & OT, define a secure architecture for ICS, lay enforcement zones to segregate ICS network from the Corporate/ Enterprise network by enabling strong firewalling/ intrusion monitoring policies, perform continuous monitoring and develop response capabilities to combat cyber-attacks/ intrusions. Additionally, the awareness level of the entire workforce should be escalated to ensure they are ‘cyber risk-aware’ and comprehend how crucial it is to incorporate ‘security sense’ at work. Since cyber-attack aimed at ICS environments heavily leverage physical security weaknesses to introduce a cyber-physical impact, it is quintessential to consider robust physical safeguards to protect marshalling rooms, control equipment, and the overall perimeter of facilities.
The "security" factor for DOF primarily focuses on the availability of the systems, minimizing downtime risks which is of paramount importance for Oil & Gas business. This paper focuses on KOC's comprehensive approach to secure its critical assets within DOF which comprises people, process and technology components that contribute towards achieving KOC's business objectives.