bluuebunny/crossref_metadata_2025_split huggingface dataset:
An Integrated Approach for Sustainable Development of Mature Field Using IOR Techniques: A Case History of Oligocene Sand of Upper Assam Basin, India
Authors: Kumar Manish , Yomdo Saloma , Pandey Ashutosh Narayan 
Published: October 2015

Abstract
Sustainable development of a mature field depends on various factors, which can be categorized into well level and reservoir level. This paper is a summary of experience of various techniques used at well level and reservoir level. The objective is to sustain/increase the level of oil production and reduce watercut using various completion methods & pressure maintenance.
This Paper will elucidate a Field Development Plan for a mature field. Several possible options were tested like 1. Possible workovers 2. Combination of Horizontal and Vertical wells based on firm and dependent locations 3. Infill short lateral wells 4. Optimal production rate to minimse pressure decline by limiting the gas production and hence putting a check on GOR 5. Water injection strategy 6. Intelligent Oil Field Completion using ICD (Inflow Control Device). For the purpose of testing the best possible course of action; the reservoir was modeled and history matching was done with satisfactory results. Prediction Strategy was then deployed at simulation stage. The financial analysis for all the prediction scenarios were also carried out using Net Present Value (NPV) method to check the feasibility as well as profitability of the various envisaged Production Strategies.
Based on the analysis, the maximum recovery was obtained from a combination of infill wells and ICD completion, but on monetary grounds, the best case consists of workovers and horizontal wells to tap the oil from segregated pockets. In the end, a comprehensive and extensive comparison of all the possible way-through options are discussed with pros and cons of each one. A sensitivity analysis was performed on economic parameters (e.g. crude oil price, operating cost, Taxes, Royalty, capital expenditures) to analyze impact on various economic indicators.
This Paper presents novel ideas into the ever expanding sphere of Field Development. It presents an extensive review of the various aspects of mature field development and their economic analysis. The field in discussion is Makum-North Hapjan which contributes around 40% of total production from OIL's fields in North-East India. It has been under production since 1993, with 62% of the production coming from horizontal wells.
Successful DST Methodology Adopted in Highly Deviated, Deep, Sour & HPHT Exploratory Well: A Case Study
Authors: Al-Ibrahim Abdulla , Al-Bader Haifa , Al-Salali Yousef , Duggriala Vidya sagar , Ayyayo Manimaran , Subban Packirisamy 
Published: October 2015

Abstract
Exploration in the state of Kuwait focuses on finding light oil and gas from deeper, HPHT and naturally fractured tight gas and condensate Jurassic Reservoirs. These reservoirs are drilled with high Oil Base Mud (OBM) densities (16–20.8ppg). The existing surface and subsurface constraints resulted in changing the proposed well location, which resulted in changing the well profile from vertical to highly deviated well. Having a deep HPHT well in highly deviated manner causes more complexity while drilling and testing the Jurassic formations. 78.2-degree angle deviated well with several side tracks and two doglegs was drilled to a depth of around 20,000-ft.(MD) to delineate the potential of the deep reservoirs. Well intervention operations were considered potentially risky due to the presence of hazardous well conditions such as HPHT and high H2S concentration. Keeping in view of well profile and hostile environments, it was very challenging task to conduct a short term well testing (STT) in these deep reservoirs.
Tractor was used in the highly deviated sections with more than 50-degree angle to record the cement quality logs with Wireline. The target formations were perforated using high temperature and high shot density TCP guns in overbalance condition using drill-pipe. Two separate Drill Stem Tests (DST) consist of tester valve, multi-cycle circulating valve, two rupture disc valves, Down hole sampler and Down hole memory gauges were used to test two different deep high pressure and sour reservoirs. Using of 15 K Coiled Tubing with total length of 20,000 ft for well activation and stimulation assisted the well intervention during the STT.
Careful planning, proper selection of equipment & materials, detailed well test program and procedures resulted in a safe and successful testing operations in such extreme well conditions such as unconventional well profile, HPHT, and presence of H2S. For the first time in Kuwait, a highly deviated exploratory well with complete set of DST tools was successfully tested and proved significant amount of light oil and gas from a hostile reservoir.
This paper describes and discusses the challenges encountered while drilling and testing an exploratory well and the achievement of overcoming these challenges which leads to successful well testing.
Shrouded ESP with Y-tool Enables Virtually Unlimited Access to Completion Interval for Well Intervention and Surveillance Operations
Authors: Anthony E.. , Al-Mutawa M.. , Al-Sharhan G.. , Jha A.. 
Published: October 2015

Abstract
Deviated wellbores are more common-place in the industry in recent years as Maximum Reservoir Contact (MRC) is the preferred strategy in wellbore construction. These high-angle, tortuous wellbores, however, have now limited the artificial lift options to Electric Submersible Pumping systems which are capable of sustained life cycles in high-watercut, low-pressure, and/or low-rate completions. Production logging and Coiled Tubing intervention in multi-layered completions and/or multi-compartment horizontal laterals equipped with Electrical Submersible Pumping systems has customarily been a major challenge, especially when the bypass fluid velocities are below the motor-cooling threshold for a conventional Y-tool configuration.
An innovative design comprising of a shrouded Electric Submersible Pump with Y-tool combination is able to facilitate access to any completion that requires production logging and/or CT intervention. At relatively low fluid rates, the shroud over the Electric Submersible Pump increases the fluid bypass velocity alongside the submersible motor for the required cooling. This shrouded Electric Submersible Pump configuration is conventionally used where the production flow rates within the wellbore are insufficient to generate the fluid bypass velocities necessary for optimum motor cooling. The Y-tool in other completions allows access for any type of wireline or Coiled Tubing-conveyed intervention for surveillance and and/or treatment operations. Previously, if a completion required a shrouded ESP, conventional Y-tools were precluded, due to the limitation of the production casing inner diameter. A specialty Y-tool was designed to accommodate conventional bypass tubing that has sufficient internal clearance for standard wireline tools together with a crossover adapter for the ESP shroud.
This combination of conventional bypass tubing and Electric Submersible Pump shroud in the same wellbore, is limited to 9⅝″ casing where the shroud outer diameter and the bypass pipe outer diameter must have sufficient clearance between each other and sufficient stand-off from the inner diameter of the production casing. The Electric Submersible Pump shroud ensures optimum motor cooling and extended system run life, especially at lower flow rates.
This innovative technology is now scheduled to be standard equipment in all Electric Submersible Pump completions in production casings with Outer Diameter equal to or greater than 9⅝″. Diagnostic wireline and Coiled Tubing-conveyed surveys, remedial and stimulation treatments can now be performed thru-tubing in Electric Submersible Pump completions without costly rig workovers. The availability of these services affords timely intervention to arrest increasing watercuts in Waterflood offtake producers thereby reducing the overall baseline production decline rate.
Contractor Safety Management
Authors: Chakrapani Ravi , Al-Qallaf Yousef 
Published: October 2015

Abstract
Oil and Gas processing operations comprise of numerous activities that are hazardous in nature including dangerous equipment and harmful process fluids. Contractors are the key and major work force in all construction projects in Oil & Gas sector. Managing Contractors' Safety has become extremely challenging in view of the large number of contractors' work force deployed/spread over many oil fields for execution of various projects including strategic / complex in nature and importance. Being an industry leader of the Kuwait state and with an objective of becoming regional leader in Middle East, Kuwait Oil Company (KOC) is working to manage the issues related to contractor Safety Management effectively. West Kuwait (WK) fields in KOC are situated in the desert areas predominantly and comprises of oil fields such as Umm Gadair, Minagish, Dharif, Abdaliyah etc. The operations spread over these fields make it really challenging in managing the contractors and their HSE performance.
In order to improve and sustain the progress of Contractor safety Management, a systematic approach process was developed to evaluate and monitor by adopting various themes/aspects involving all levels of KOC Management in line with the Company's HSEMS procedures/Standards applicable to construction worksites and site offices of West Kuwait projects and contractors.
Continuous Operation Model for Tight Gas Development in Sulige Gas Field, China
Authors: Naizhen Liu , Ming Liu 
Published: October 2015

AbstractSulige gas field of China is a typical tight gas reservoir with the features of low-pressure, low-permeability and low-abundance. During almost twenty years of development, low production and high cost are the two most important elements which hinder its quick development. In the beginning, vertical wells are the main well type used in the gas field. However, large number of collected data and analysis from the vertical wells shows that horizontal well can be more effective. To pilot the development result of horizontal wells, several pilot zone and blocks are selected. In the second half of the twenty-first century's first decade, horizontal drilling and completion have been widely used in this field. Considering the advantage of horizontal wells compared with the vertical wells, gas production has been substantially increased.With the success of shale gas development in North America, many of advanced technologies and management skills have been frequently applied to other kinds of oil and gas field, tight gas, tight oil, etc. Due to the job complexity and economic expense, technical skills and management experiences have been significantly improved, which is beyond everyone's imagination, especially for the cognition of unconventional resources, development methodology, intersecting job procedure, etc. All these improvements ensure the breakthrough of development in Sulige gas field in the last 5 years.This paper aims to describe the application of continuous operation model, which is also called factory operation model, in block Su53 of Sulige gas field from the technical point of view. First, the background of block Su53 will be introduced, including geological characteristics, formation property, development history, etc. Second, continuous operation procedure will be described, which covers the intersecting operation among several kinds of specialties. Third, the successful application of continuous operation model in pad Su53–82 which includes 10 horizontal wells, 2 directional wells and 1 vertical well and the applied technologies will be introduced. Finally, we compare the gas production and economic benefits with the regular wells.
An Overview of Different Chemicals Used in Designing Cement Slurries for Oil and Gas Wells
Authors: Al-Yami Abdullah S. 
Published: October 2015

Abstract
Cement must be designed in a way to ensure acceptable properties such as mix ability, stability, rheology, fluid loss, and adequate thickening time. Different chemicals are used when designing cement slurries. These chemicals are used as retarders, fluid loss additives, dispersants, gas migration additives and expansion additives.
Typical examples of compounds used as retarders include: calcium lignosulfonate, sodium lignosulfonate, sodium tetra borate decahydrate (borax), starch derivatives, hydroxyethyl cellulose and weak organic acids. Examples of dispersants are ferrous lignosulfonate, acetone, and polyxythylene sulfonate. Many additives for fluid loss are water soluble polymers such as Vinyl sulfonate based on the 2-acrylamido-2-methyl-propane sulfonic acid. To the best of the author's knowledge, there is no study that compares the performance of different chemicals in cement designs.
The objective of this paper is to detail some of the cement chemistry and to go over the chemicals used in cementing oil and gas wells and their mechanisms of actions.
Building Safety Culture within Novice Engineers
Authors: AlKazimi Mohammad A. , Altabbakh Hanan M. 
Published: October 2015

Abstract
The volitile nature of petroleum products as well as the integral convolution of the process urged the petroleum industry to pursue techniques to recognize, assess and encompass possible hazards. Together, both government agencies and non-profitable professional societies guide industry leaders with best- recommended practices. Hence, they aim at improving operations mamanement and ensure a safe working environment with processing facilties.
Regretably, accidents due to both human errors and electromechanical failures still happen and result in numerous consequences. As a result, critics have raised concerns about the petroleum industry's safety and risk mitigation credentials and question its ability to prevent major accidents. Therefor, and in to establish a rigid safety culture, the gap between both the academia and the industry need to bridged to enhance the knowledge base of safety in the petroleum industry.
The purpose of this paper to defines the establishment of "HSE Risk mamangement in the petroleum industry" course in the Petroleum Engineering program at Missouri University of Science and Technology. Not only it is designed to cover the technical aspects of HSE in the petroleum industry, but it also enhances the overlooked soft skills, ethical responsibilities, and creating safety culture.
First Application of Plasma Technology in KOC to Improve Well's Productivity
Authors: Chellappan Suresh Kumar , Al Enezi Fatma , Marafie Hussam A. , Bibi Amro H. , Eremenko Vasiliy B. 
Published: October 2015

Abstract
Stimulation is a well-practiced technology in oil industry to improve productivity or injectivity of a well. Plasma Pulse Technology (PPT) is a special kind of stimulation technique where oil production enhancement occurs without formation damage and without using chemical agents. PPT is based on scientific research in the areas of Geology, petro-physics, blasting theory, acoustic, wave theory and resonance theory.
Well RA-000A was identified for plasma application mainly to stimulate the very tight layer SID2 which otherwise difficult to produce through conventional perforation and to have positive production impact on nearby well RA-000B. Before application of this new technology, three intervals were perforated with last production rate @ 196 bopd with 90% water cut and closed for pressure. PNC log (sigma log)was recorded which shows that out of three perforated interval, the bottom COAL2_UCH layer having very high water saturation, the top of COAL2_UCH is having little water saturation and COAL1 LCH is almost dry. The porosity and permeability of the bottom layer of COAL2 UCH is very good whereas COAL1 LCH is having moderate rock quality. It was decided to isolate COAL 2 UCH due to very high water saturation. Also, decided to add SID layer which is very tight with low porosity and permeability
Nodal analysis was carried out to estimate the production potential after isolating the water producing layer and adding SID layer. The prosper model estimated that the selected interval will produce @ 800 to 1000 blpd with the PI of 1 to 1.5 bbl/day/psi.
After successfully executing PPT for the first time in KOC, the Production GOR test conducted after a month showed stabilized production rate of 1279 blpd, 363 bopd with a PI of 2.25 bbl/day/psi, which is two times more than the earlier PI. The liquid production is above the model predicted and achieved an incremental oil gain of 167 bopd due to plama pulse technology, ie an increase of 85% from the initial oil production rate. In addition to this, immediately after plasma application, observed 81 psi increase in pump intake pressure of the nearby well RA-000B which is 400m away from this well. It is planned to carry out plasma pulse stimulation technique in more candidates including Rigless application.
Compaction Assessment and Evaluation of Liquefaction Potential of Offshore Artificial Island Based On ‘SPT’ and ‘CPT’ Data
Authors: Konni Ganapathi Rao 
Published: October 2015

Abstract
In Oil and Gas industry, offshore platforms are very common in most of the regions. But, despite the fact that there may be risk of liquefaction, it is also seen that some projects demand the requirement of construction of offshore artificial islands to set up all the required facilities of the Oil and Gas plant. Therefore, in this study, a live project having offshore artificial island, about 84km offshore, has been taken and an attempt has been made to assess compaction levels achieved for offshore artificial islands. Subsequently, liquefaction potential has been evaluated based on both SPT, N and CPT data. Eventually, studied the reliability of the data for the liquefaction assessment.
The findings from this study revealed that: 1) Stringent compaction acceptance criteria shall be de-veloped based on the predefined factor of safety against liquefaction and make sure that the compaction works are in compliance to the criteria; 2) Liquefaction analysis based on the CPT data is reliable as the CPT data gives continuous profiles and represents the actual site conditions, compare to that from the SPT.
It is recommended that special care shall be taken while executing compaction works on such artifi-cial islands so as to avoid any risk of liquefaction.
Utilizing Composite Pipe Wrap Technologies to Restore Corroded Pipework to Operating Compliance
Authors: Oharriz Osmay , Bateman Colin 
Published: October 2015

Abstract
This paper endeavours to demystify, simplify and explain the reality of designing and applying compliant composite pipe repairs by presenting application case histories and field experience. The paper discusses the background in the development and the challenge faced by operators in applying the ISO standard to damaged pipework in the field and reviews the options for the pipeline engineer to overcome these difficulties through additional composite repair technologies.
Composite pipe repair technology has been applied in the offshore oil and gas industry for many decades, the introduction of the ISO TS 24817 standard in 2006 offered pipeline engineers the possibility to prescribe pipe repairs using composite wrap systems compliant to the requirements of the ISO standard. The engineered composite repairs, qualified, designed and installed in accordance with ISO TS 24817, provide both external corrosion protection and structural strength to the pipework/pipeline.
The paper will present the data by; discussing common misconceptions regarding composite pipe repairs and offering solutions to overcome the challenges on-site to meet the requirement for the application of compliant systems. Investigating the range and type of defects that are encountered, both through internal and external corrosive attack and reviewing the possible repair methodologies in cases where, due to the severe metal loss that has occurred and the degradation process, without additional repair techniques a compliant system could not be applied. In addition, commenting on different pipe geometries and configurations and their suitability for composite repairs.
Further comment/discussion on the use of composite wrap systems for structural repairs on equipment other than pressure vessels will also be included.
Integrated Solution to Mitigate and Prevent Black Powder Phenomena in West Kuwait Operation Facilities
Authors: Al-Qabandi Salman , Khuraibut Yousef , Al-Inzi Mohammed , Al-Dashti Adnan , Al-Nabhan Talal , Al-Enzi Ahmed , Jamsheer Abdullah , Kumar Pardeep , Thirumaran A.. , Srinivasan B.. , Al-Ghareeb Tahani 
Published: October 2015

Abstract
Black Powder has identified as a significant problem in all areas of hydrocarbon production facilities and transit or export lines. The phrase ‘Black Powder’ in the oil industry used to describe a contaminant found from wellhead, Gathering Centers and gas export lines. The constituents of black powder are known to adversely affect the efficiency, integrity and reliability of oil and gas production, refining and transportation. Its combines of corrosion material such as Iron sulfide, Iron oxide, Wax, Asphaltene, silt and sands. Its vary from one location to another within the process of the oil and gas production. Its presence in all areas of upstream, midstream and downstream oil and gas production. It's affecting the flow assurance and quality of performance of the facilities from compressors, vessels, tanks, sensors and pipelines and finally impacting the refinery efficiency. Its major problem start to be present recently in oil industry which many different operators have different misunderstanding to overcome these phenomena of the black powder. The paper will be to look at best strategy and solution success to mitigate the problem of the black powder in Kuwait Oil Company from west Kuwait operation facilities to Refinery. It will highlight also roots cause, Impact and prevention plan. It will show how it help reduce gas flaring, minimization facility shutdown, reduce Flowlines leaks, and optimize chemicals consumption in operation facilities which lead to cost optimization.