bluuebunny/crossref_metadata_2025_split huggingface dataset:
Improving The Electrical Submersible Pumps Operational Time By 50% Using The Six-sigma Procedures
Authors: Ahmad M.. , AL-Refai S. I. 
Published: October 2015

Abstract
Electrical submersible pumps (ESP's) downtime is one of the most significant concerns that affect the oil production sustainability. Various defects as electrical trips, mechanical issues, under or over load trips and manual shut off are keeping the pumps off operation that would suspend the well productivity. The downtime of ESP's generized by generators globaly is exceeding an average of total 2 days per well from a population of 400 pumps. This is directly reducing the total daily production. The objective is to reduce the operational downtime by 50% after allocating the most marking defects to increase the pump's spinning time and maintain the wells’ production.
Statistical study using the Six-sigma procedures is employed to accomplish the downtime reduction. The problem is defined as reducing the ESP's downtime by 50%. The spinning hours are measured in daily bases from 400 wells and the downtime is calculated. Moreover, each defect is categorized to a main reason branch. The branches are mainly consisting the reservoir characterizations and the formation type. In addition to that, the data is analyzed using the ANOVA analysis road map and the hypothesis testing procedures.
The analysis showing that most of the defects are electrical ones, that is because of using diesel generators to energize the pumps. An improving process is encountered to overcome this problem by substituting the generators with the government electricity. In the other hand, high amount of defects are considered as reservoir effects while the pumps are tripping because of under or over load. The main reason behind this kind of pumps’ tripping is the pump design and the high water cut of the well. An appropriate pump design procedures are organized to reduce this kind of defects. Also, optimization practices are developed to set the right pump situation that would enhance the well productivity and minimize the operational downtime.
In order to control the ESP's operation, several monitoring methods and applications are used for taking actions toward any abnormal pump behavior as V-Monitor, SCADA and daily ESP reports.
KOC's Effort Towards Better Fiscal Metering
Authors: Alanzi Mishaal 
Published: October 2015

Abstract
As part of the continual improvement and expansion of Kuwait Oil Company’s (KOC) infrastructure, the company is currently executing mega fuel gas and liquid fuel projects for the ever increasing demand of energy consumption. The major overhaul of KOC’s existing network is being improved and expanded by three mega projects. Two of which are identical and handle the demands of Minsitry of Electricity & Water (MEW) North & South Kuwait power stations. Whereas, the 3rd project, which is called the Telemetry Project, is being implemented to provide telemetry, automation, leak detection system and fiscal metering for the whole network. Furthermore, this telemetry project has an independent SCADA system to meter, monitor and control large diameter cross-country pipelines remotely from ultra-modern control rooms; Consumers Network Management Center (CNMC) and Secondary Network Management Center (SNMC). The total gas delivered under these projects exceeds four BSCFD and includes custody-transfer class metering skids and associated systems. Custody-transfer measurement is of great importance within KOC’s downstream business in order to meet Kuwait Petroleum Corporation’s clients, large and small users. This technical paper shows the positive impacts and huge contributions these major projects made. Another focus is on the different philosophies used in the metering skids and various applications of flow meters in the projects. Dew Point Depression Units (DPDU) is the first facility ever built in Kuwait and such decision shows KOC’s emphasis in opting for technology beyond traditional use. Furthermore, a comparison of the gas and liquid flow-metering skids under the three projects gives us a very fruitful analysis in terms of selecting the best features and avoiding the shortcomings of all three designs. In addition, the analysis compares the flow-spitting or control switching, proving systems, calibration procedures and flow-computation besides other features. In conclusion, the state-of-the-art technologies of flow metering solutions made huge and significant improvements as well as reached new levels of reliable flow measurement. Whereas, in the past, a certain and limited number of applications were available and used which resulted in poor flow measurement and higher uncertainty/error. This particular comparison, between the old and new consumers networks, emphasizes KOC’s position in achieving and obtaining innovative flow measurement solutions.
Implementation Of Non-man Entry Technology- An Automated Technology for De-sludging & Cleaning of Tanks
Authors: Al-Dousary Sharian , Dharan Ganga Prasad 
Published: October 2015

Abstract
De-sludging is the process of removal of sludge from the tank and dispose it in an environmentally friendly manner. It is required to be carried out when the sludge level increases in the tank and affects the operation of the tank or to carry out the maintenance activities of the tank.
Generally De-sludging is carried out by man entry method in which personnel enters the tank wearing all the required PPE’s and remove the sludge using various tools like Hydro Dozer, Shovels, Scrappers and Movable containers. The removed sludge is transported to the Crude Recovery Unit by vacuum tankers for further treatment.
Manual method of de-sludging carries following difficulties:
Working environment inside the tank is unsafe/dark and Workers are exposed to hazardous gases like H2S, Hydrocarbon, etc. Negative Environmental Impact during handling of sludge The activities take long period and requires high manpower(15-30 personnel) Sludge with very high solid content cannot be treated through crude recovery system.
Non-man entry technology is the method by which the sludge from the tank is taken out without any personnel entering the tank. The treatment of the sludge is carried out through an automated process inside the bund wall of the tank.
This process utilizes nozzles fixed on tank roof (by cold cutting) to spray the oil into the tank to shear and re-liquefy the sludge in order to transfer it from the tank. The sludge taken out from the tank drain nozzle is circulated through the sludge treatment unit which consists of centrifuge and high/low speed decanters. Once the recovered oil achieves the desired quality as per the lab results, it is transferred to the adjacent designated tank. Remaining layer of oil from the tank is removed by washing with fresh water followed by washing with water mixed with detergent. Tank manholes were opened and fixed with pneumatic blowers for ventillation. Workers enter the tank based on the clearance by Company’s safety person to clear the residues and to carry out the cleaning of areas inaccessible to the cleaning nozzles.
Recently, Kuwait Oil Company successfully implemented the non-man entry in two tanks and found having following benefits.
Safe, Healthy and Environmental friendly solution with reduced emission of hydrocarbon No workers enter the tank during de-sludging & cleaning and hence reduces the exposure to various hazards Closed system, not exposed and Continuous monitoring Activity duration can be reduced up to 50% of manual method Totally automated process and hence requires less manpower (5 personnel). All types of sludges irrespective of the oil content can be treated Totally safe in explosive and dangerous areas
It is the first implementation of such technology in K-Companies that has improved the HSSE performance and added great value to the maintenance practice of the Company.
Thickness of Concrete and Steel Front Wall Claddings for Various Blast Pressure in Blast Resistant Buildings
Authors: Singh Jitendra Pratap , Roy Anindya 
Published: October 2015

Abstract
Blast resistant buildings consists various combinations of wall claddings and structural system. Cast-in-place concrete and corrugated steel plates are most common front wall claddings that are being used in the industry. Wall cladding is an important element of the building because this is the first barrier of the building against the blast wave. Its dynamic interaction with the blast wave depends on its geometry, material properties and blast wave parameters. While ductility and fundamental period of vibration are the primary factors which controls the resistance against blast. Wall claddings are attached to the structural system, therefore the blast reactions from the edges are being transferred to the structural system. This reaction is function of ductility and fundamental time period of wall cladding.
Construction of concrete front wall needs some flexibility in schedule of the project while corrugated steel plates require higher budgetary demand on the project. Therefore in the present paper, a parametric study being done to calculate thickness of front wall for various blast pressures, duration of blast pressure, reinforcement, span of wall for a simply supported end condition, which is the most common boundary condition in the practice. Ready to use charts are prepared to estimate the quantities in design.
A Comprehensive Surveillance Plan for Steamflood Pilots
Authors: Sanyal T.. , Al-Khamees W. K. , Bagheri M.. , Abdulraheem H.. , Al-Sane A.. , Al-Ali Yacob 
Published: October 2015

Abstract
The development of the vast viscous oil resources of Kuwait is considered a very important strategic goal of the country. The first phase of development plans is under implementation to meet a target production of 60 M bopd by a combination of cold flow and cyclic steam stimulation (CSS) followed by steamflood to have optimum recovery from this resource. The thermal development plan for the viscous oil resources, targeting high recovery factor from this resource, is considered to be the first EOR project in Kuwait. The thermal project starts with Cyclic Steam Stimulation followed by steamflood. To optimize the process and maximizing recovery, three pilots have been planned for evaluation of these technologies in this field. A detailed plan was developed to ensure quality surveillance information is obtained to support this pilot performance interpretation. This present paper summarizes the salient features of that surveillance plan and how the planned data can be interpreted, to obtain maximum value from the pilots.
First the impact of known reservoir uncertainty parameters was evaluated through simulation studies and field testings, to evaluate their potential to become major risk parameters for the project. A commercial uncertainty analysis software to identify risk factors was used for this study. A comprehensive surveillance plan for evaluation of the potential risk parameters in the pilots was then firmed up, based on available technologies in the industry.
The study identifies that an integrated approach is needed involving the completion plan, surveillance options and project goals to optimize learning from the pilots. A realistic surveillance plan, which caters to the different completion plans being evaluated in the pilots, was firmed up. The study also recommends frequency and resolution needed in the surveillance data, for meaningful interpretation of results.
A comprehensive surveillance plan in the pilots is considered a key success factor in EOR projects. With increasing demand for fossil fuels in future, evaluation of EOR technologies through pilots would continue to remain a desired option, to reduce project cost and risk. The risk assessment approach elaborated in this study is expected to have relevance in similar EOR projects all over the globe.
Processing Heavy Crude
Authors: AlRashoud Anwar M. 
Published: October 2015

Abstract
Kuwait has abundant proven reserves of oil and recent discoveries suggest that Kuwait has significant heavy oil reserves as well. Heavy Oil in Kuwait ranges from conventional (easy to produce) 16 °API in lower Fars and unconventional (difficult to produce) tight oil and Tar-Mats. Developing these reserves in an environmentally compliant and sustainable manner is a national priority. The challenge of increasing national production to 4 million barrels per day will depend in large part on our ability to develop and adapt the technologies necessary to be able to exploit these heavy oil reserves.
There are around 160 types of crude oils being produced worldwide and the price differentials between crude oils can be $15 /barrel or higher. Refiners find themselves faced with the difficult question of searching for crude blends to maximize the use of their existing assets or to choose crude blends, which will require additional capital investment but will offer opportunity to increase return on investment. As per World Oil Outlook by OPEC, a continuation of moderate light-heavy crude differentials in the medium-term is indicated, followed by a progressive widening in the long-term. The moderate differentials in the short-term stem from the existence of excess refining capacity and the lightening of the global crude slate. The long-term trend toward a widening of the differentials, with heavy sour grades especially affected, is mainly due to a return over time toward a more balanced downstream as well as a gradual shift toward a more heavy crude slate. This will be alongside continued declines in inland and especially marine residual fuels demand. In addition, the on-going trend toward sulfur reduction in transport fuels will further differentiate crude oils depending on their sulfur content. In General, an Increase in Light-Heavy differential on both crude side and product side indicates better Refining Margins leading to improved profitability.
Historically, the petroleum industry supply chain has been divided into three discrete sectors: production, transportation and refining. Typically, crude is produced and made ready for transportation by production operations, and it is transported via pipeline or ship, train or truck to more sophisticated and complex refineries. Once at the refiner, the crude oil is refined into transportation fuels and other high-value finished products. The downstream sector of the hydrocarbon industry continues to optimize processing schemes to take advantage of the lowest-cost crude oil, of which a significant portion of the "opportunity crudes" are heavy oils.
Maximizing domestic processing of Heavy/Sour crudes is a KPC 2030 Strategic Direction for KNPC. Accordingly, Al-Zour Refinery (ZOR) is planned to handle heavy crudes. However, Processing of Heavy Crude in an Oil Refinery is an opportunity as well as Challenge. In my presentation, I will highlight the same from a refining business prospective.
Excellent Stimulation Results in Deep Carbonate Reservoir in Marrat Formation in Magwa Structure in Greater Burgan Field Kuwait
Authors: Snasiri Fatemah , Abdulrazzaq Eman , Tirkey Naween , Kotecha Rohit , Gazi Naz H. , Al-Othman Mohammad , Al-Sabea Salem , Ali Farida 
Published: October 2015

Abstract
Marrat reservoir in Magwa field in Greater Burgan, Kuwait is a carbonate heterogeneous reservoir belonging to Lower Jurassic. Marrat is classified as a tight reservoir with an average permeability of 17md and contains light oil of 38deg API. The formation is around 2400ft thick divided in three sub layers namely Upper, Middle and Lower Marrat. Middle Marrat is the main oil reservoir which has been perforated and tested to be oil producing in almost all the 30 drilled wells. The reservoir consists of Grainstones, Packstones, Wackstones and Mudstones. Marrat was put on production in 1984 and solution gas drive is the main drive mechanism. The reservoir is naturally depleted due to limited water aquifer. The reservoir pressure declined 17% from the initial reservoir pressure within 15 years to current pressure of around 8000 PSI. Field Development Plan envisages pattern and peripheral water injection and facilities development for water injection is planned. Asphaltene flocculation at wellbore, tubular and surface facilities has been recognized as a severe problem. One of the options to avoid asphaltene problems in the reservoir, including the near wellbore region, is to maintain reservoir pressure and flowing BHPs above the asphaltene onset pressure (AOP) of ~ 6500 PSI.
Formation fluid contains around 1000 ppm of H2S and 4% CO2 which throws a corrosive environment also to tackle with. The well head equipment with present metallurgy often leaks on pressure tests and there is a plan to replace during future work over jobs. Coil Tubing Cleaning of tubular with light aromatics is a routine operation to maintain production from wells.
Increased demand of oil necessitated safely increasing oil production from Marrat reservoir. Keeping in view the challenges, a multi-disciplinary team was formulated to look into all possibilities. Focus was on Acid Fracturing Technique which had proved to be successful in the past. However with advancement in acidizing and diversion chemicals, the new system was field trialed.
This paper will discuss the process to select the wells and successful attempt of acid fracturing in two wells to tap oil from new areas.
Production Enhancement Strategy in Lower Burgan Reservoir: Greater Burgan Field, Kuwait
Authors: Naik Vinay , Jasem Mariam , Al-Enezi H. S. , Al-Matroud F.. , Haryono R.. , Behera P. K. 
Published: October 2015

Abstract
A comprehensive development strategy for BGSL1 reservoir of Burgan Formation, deposited in Lower Cretaceous, of Greter Burgan field, Kuwait was formulated to increase the production of the low productive heterogeneous reservoir. The BGSL1 reservoir was deposited in shore face dominated coastline with protected tidal bay. The heterogeneous nature and low Sand: Shale ratio makes development of this important reservoir difficult. After studying the production performance of BGSL1 reservoir, mainly four technical challenges are identified. These are 1) wet production, 2) low productivity index, 3) short self-flow life and frequent work over needed and 4) Complexity in terms of lower API crude, multiple oil-water contacts and heterogeneity.
Initial study for BGSL1 reservoir was started by revisiting all the wells drilled to BGSL1 reservoir. Remaining Oil distribution maps of each sub-layer were prepared which had given clear understanding of potential of this reservoir. BGSL1 reservoir remaining oil map was divided into several compartments. On the basis of volume, 24 compartments were identified as under-developed in terms of their current off-take rate to current remaining oil volume. Some of the compartments are preferred for development than other due to development opportunities for more than one reservoir.
Development of BGSL1 is highly challenging. The reservoir may require planning single dedicated completions with artificial lift. A novel approach was adopted to screen the candidates for artificial lift, which was based on highly underperforming wells, where self-flow with good rate is not possible due to high water cut and declining production. Evaluation of these ESP candidates were done with remaining oil column, bypassed oil & partially swept zone potential with rock quality, PI measurement and historical plot of liquid rate & water cut to review the well deliverability and to estimate water cut with ESP.
The technical challenges were resolved to a great deal. For reservoir complexity like multiple oil-water contacts & heterogeneity, unit wise estimation of remaining oil has helped. High viscosity oil mapping helped to isolate low API / high viscous oil. It was seen that study helped to achieve a rise of oil production and using these practices helped to reach highest production over last decade.
Selecting the Optimum Waterflood Concept and Water Quality Specifications to Maximize Production
Authors: Aristov Sergey , van den Hoek Paul 
Published: October 2015

Abstract
Waterflooding is the most widely used secondary recovery concept in the oil industry. Once embarked on, it becomes vital to assure the proper planning and execution of a project. There are multiple examples of things that can go wrong if the project is not properly designed, and/or if the practices and standards are not adhered to. These include loss of injectivity, out-of-zone injection, early water breakthrough, loss of reservoir containment, significant CAPEX/OPEX overruns, injector-producer shortcircuiting, reservoir souring and scaling issues etc.
Waterflooding concept and corresponding water quality is one of the overarching themes in a waterflood project. It requires an integrated multi-disciplinary approach to conclude on an optimum design and strategy. Some of the issues that need to be addressed in the first place are: –matrix of fractured regime–injectivity decline and necessary water quality specifications–fracture growth over time and its impact on sweep–risk of out-of-zone injection and loss of reservoir containment.
Realising the magnitude of these questions, Shell has developed a suite of tools to tackle these issues and help in adequate designing and optimization of waterfloods. They include: –ASCET (Actual and Simulated Coreflood Evaluation Tool). On-site coreflood tests at real-life conditions, measuring formation impairment as function of water quality.–FORDAM (FORmation DAMage) software. Estimation of injectivity decline when no ASCET tests are available.–PWRI-FRAC (Produced Water Re-Injection FRACture modelling). Quantification of fracture growth as a function of water quality and injection rate.–FRAC-IT (FRACture IT). Model the impact of fracture growth. Assess risk of out-of-zone injection and impact on sweep.
Utilising these tools helps make informed waterflood decisions, improve water management, reduce (or eliminate) water disposal, lower environmental impact, avoid unnecessary CAPEX/OPEX.