bluuebunny/crossref_metadata_2025_split huggingface dataset:
Towards a Zero-Skin Well Completion with Non-Damaging Non-Corrosive Enzymatic Wellbore Cleanup Fluids
Authors: Ghosh Bisweswar , AlCheikh Ismail , Ghosh Debayan , Osisanya Samuel 
Published: November 2019

Abstract
The objectives of this study were; (1) selection of size distribution of bridging particles of polymer-based drill-in fluid based on the actual reservoir porosity distribution in order to minimize the internal filtration damage, and (2) to develop a non-corrosive wellbore cleanup fluid comprising of a specially designed bio-enzyme and in-situ organic acid precursors to remove the external filter cakes and bring the skin close to zero prior to well completion. Drill-in-fluids were formulated and developed based on Ideal Packing Theory (IPT). The calcite particle size simulation was conducted using a particle size simulator based on IPT using FMI log information from a carbonate reservoir. Xanthan-starch specific bio-enzymes were screened and optimized to achieve complete dissolution of the polymers present in the mud-cakes. Acid precursors were formulated and developed to dissolve the calcite particles and at the same time keeping the corrosion level below the maximum acceptable limit. Compatibility tests between the acid precursors and the bio-enzymes were performed. The final cleanup formulation was subjected to corrosion studies at dynamic conditions. The entire development was verified at reservoir conditions through core flooding experiments.
The formulated fluid was tested successfully against ceramic disks and carbonate core plugs by performing core-flood tests. The polymer based drill-in-fluid resulted in a very low permeability filter cake (&lt;0.1 md), preventing internal filtrate damage significantly. Deposition of a very low permeability filter cake was achieved on carbonate core plugs which results in reduced damaging invasion. Several ester hydrolysis reaction kinetics were studied and finally one combination was chosen as the suitable acid precursor, because of their ability to generate required concentration of acid within three hours of hydrolysis at downhole condition. The best acid precursor satisfied the requirements by generating 3% of acid needed after 3 hours and maintained low acid concentrations for 12 hrs. The corrosion rates were found to be significantly below the industry limits and use of acid corrosion inhibitor is not necessary. Return-permeability of mud damaged carbonate core plugs was as high as 96% after exposing to clean-up solution.
A new drill-in fluid has been developed and its filter-cake deposition was completely cleaned up with enzyme-acid precursor combination. Normally wellbore cleanup fluids are highly acidic and need corrosion inhibitor. The new formulation was effective in minimizing corrosion of downhole tools without the use of corrosion inhibitors.
An Innovation Retrofit Solution Converting ICD to AICD Completion Leading to Enhanced Oil Recovery and Inventory Optimization
Authors: Khunmek Thanudcha , Abu-Jafar Feras , Chigbo Ikenna , Laoroongroj Ajana , Mohd Ismail Ismarullizam , Parrott Keith 
Published: November 2019

Abstract
This paper describes a pilot program for the application of an Autonomous Inflow Control Device (AICD) by retrofitting an existing ICD completion for reservoir optimization. New drill horizontal wells were required to be completed with AICD's to enhance recovery with existing ICD completion materials in inventory desired to be used. The workflow for establishing the decision change from ICD to AICD completion and the completion design process change is discussed.
The well program was selected to demonstrate the effectiveness of AICDs in the Jasmine asset, a current field development in Thailand. ICD screens had previously been purchased for a different application but were unused. To reduce overall project cost and asset inventory, a method of utilization the existing ICD screens was strongly desired. An evaluation was done, followed by design and development of a manufacturing process to retrofit the ICD screens with larger sized AICD housing. Furthermore, overall completion design was implemented to ensure a smooth deployment and optimized production benefit.
Multiple joints of existing ICD screens were successfully retrofitted with AICD technology locally within the region. The operator was able to reduce current inventory book levels by 20% that resulted in a direct cost saving of 40% comparing to new AICD screen cost. The field deployment of the retrofit completion was a success without any operational issues.
Despite the improved productivity and uplift in reserve recovery associated with horizontal wells, reservoir heterogeneity can cause uneven production and early water and gas breakthrough from portions of the wellbore. The AICD delivers a variable flow restriction in response to the properties (viscosity) of the fluid with water or gas flow restricted. With multiple segmentation along the horizontal section in this application, excessive production of unwanted gas and water have been limited. Installed in late 2017 and another application in 2018, production from the wells have exceeded expectation, with an uplift in recovery.
Versatile Base Oil that Breaks Drilling Barriers
Authors: Supramaniam Nandakumar , Ezani Farah Shakinah 
Published: November 2019

Abstract
This paper presents the technical development of an operator's drilling base oil produced from their MG3 plant which was evaluated through extensive laboratory studies and field trials prior to commercialization.
The base oil is based on a majority iso-paraffin component which gives an optimum kinematic viscosity, flash point and pour point for drilling applications. In addition, the drilling fluid has minimal aromatic content to fulfil international eco-toxicity standards set by CEFAS and US EPA, 821-R-11-004 Method 1619. The base oil is compatible with various oil/synthetic mud systems and additives with its low viscosity characteristic lesser than 2.4 cSt at 40 deg C which offers excellent drilling performance for Shallow and Deepwater wells. Furthermore, the base oil exhibits high flash point of more than 90 deg C to reduce potential fire hazard while drilling HPHT and ERD wells. At the same time, its superior pour point (as low as -42 deg C) suitable for storing base oil in sub-zero conditions and to be used as deep-water drilling fluid in extremely cold countries like Russia. Its unique high-performance properties provide exceptional temperature stability and optimum rheological properties throughout the extreme temperature profile of a Deepwater or HPHT well, thus resulting in a very low ECD despite drilling with high ROP.
Field trials were carried out to verify the base oil's performance under laboratory conditions. The base oil was tested as base fluid in SBM for both Shallow and Deepwater wells. The Shallow well was drilled vertically in water depth of 105M with a maximum mud weight of 14.6 PPG and bottom hole static temperature of 280 deg F. The Deepwater well was drilled vertically in water depth of 1008 M and subsequently side-tracked to a maximum inclination of 46 degree. Both wells were drilled successfully without any drilling fluid related issues as compared to severe losses experienced with respective offset wells.
A total of approximately 138 oil and gas wells were drilled by the operator utilizing their own base oil till 2018 after completing the technical evaluation in 2014. From the field trials and actual drilled wells, a comprehensive database analysis was developed for future improvisation and broader performance portfolio. The main technical challenge for the operator was to engineer a drilling fluid system with base fluid and chemical additives to obtain minimal ECD for reducing lost circulation risk. The base fluid properties are ideal for Shallow, HPHT, ERD and Deepwater applications whereby the ECD margin for Deepwater and ERD drilling is often narrow as compared to shallow wells. The successful project execution of base oil for drilling represents a significant milestone, elevating the company's base oil progress at par with other global base oil producers.
Application of Statcom Technology for the First Time in Oil & Gas Fields; Challenges and Way Forward – Case Study.
Authors: Ahmed Walid , El Mahmoud Ziad , Al Shawoush Abdulla 
Published: November 2019

Abstract
Electrical utilities are subject to voltage sags, poor power factor and even voltage instability as long as it suffers from shortage of its reactive power sources. The only mitigation to this problem is to have proper and fast acting reactive power control on the grid. This in turn will overcome the major concerns of network voltage instability, especially during the transient and sub-transients conditions such as major switching operation, and electrical faults.
In many cases, the traditional solutions of switching capacitors is too coarse and slow to stabilize a weak network.
The most advanced solution to compensate reactive power is to incorporate a STATCOM (or Static Synchronous Compensator) as a variable source of reactive power. STATCOM is an advanced power electronic system for fast capacitive/inductive reactive power supply providing reactive power compensation and, steady state and transient voltage stability, etc… These systems offer advantages compared to standard reactive power compensation solutions in demanding applications.
In order to mitigate utility network power quality problems, ADNOC Gas Processing has recently introduced a STATCOM solution in two running plants. This paper deals with the design process of customized Power Quality solutions involving STATCOM Technology to resolve network quality issue up to full commissioning of the system, elaborate on challenges and difficulties faced, and highlight how it was resolved.
Ejector Technology for Flare Gas Recovery as an Alternative to Rotating Equipment
Authors: Ainge Peter 
Published: November 2019

Abstract
A reliable flare system is an important part of most oil and gas facilities. In an emergency or similar process shutdown event where pressure relief is required, the flare system must safely and reliably handle and dispose of waste gas through burning it to atmosphere. However, outside of these emergency cases, many facilities also carry out continuous or routine flaring, where purge gas, waste gas and other low-pressure gasses are sent to flare to be burned to atmosphere.
As the environmental and subsequent legislative pressures have increased over recent years, Operators are actively looking for low cost, reliable Flare Gas Recovery (FGR) solutions. This involves recovering flare gas and diverting it away from the flare system to an alternative destination, thereby avoiding the need to burn the gas to atmosphere. Most commonly, recovered flare gas can be used as fuel gas or returned to production, providing some commercial value to the Operator.
As most flare systems operate at low pressures (close to atmospheric pressure), gas compression is required to increase the gas pressure to allow the recovered flare gas to be used as a fuel gas or returned to production.
Traditionally, rotating-type compression equipment has been employed to compress low pressure flare gas including Liquid-ring, Screw, Sliding Vane or Reciprocating-type compressors.
However, due to their reliance upon moving parts in direct contact with flare gas, rotating equipment is prone to break-down. For many facilities with an FGR system, one of the most common causes of unplanned flaring is due to the breaking-down or ‘tripping’ of FGR compression equipment, counter to its very purpose to reduce flaring. These compression devices are also adversely affected by the flare gas stream, which is often poor quality. As an example, high levels of hydrogen sulphide (H2S) is a very common characteristic for flare gas streams. This ‘sour’ gas is one of the primary causes of degradation of compression equipment. In particular, this affects the equipment seals and sealing arrangements.
This paper explores how Ejector technology (sometimes known as Eductors, Jet Compressors or Surface Jet Pumps) can be used as an alternative to rotating-type compression equipment for FGR and how the unique challenges of this duty are overcome.
Critical Offshore Pre-Engineering Survey Guidelines for Early Jackets
Authors: Athmaram Jayaprakash , Al Sayari Abdul Hakeem , Srinivasan Ashish GS 
Published: November 2019

Abstract
Presently, lower costs, tighter schedules and optimized resources drives project management teams for early production schemes which is becoming a norm among large E&P companies particularly with NOC’s. The challenging market environment has made it desirable to depart from our usual conventional platforms to early production schemes. Due to demanding schedule and urgency to achieve early production targets, sometimes the teams overlook certain critical pre-engineering survey requirements which has the potential to make or break the project.
The criteria used to determine the jacket location for such urgent projects purely depends on the main condition of reachability of the proposed wells to the reservoir and not broadly based on a broad qualitative assessment. It is to be noted that irrespective of its size, early jackets still require detailed assessment of the proposed site and it has to be established beyond doubt that the site is free from subsea interference and seabed debris. An equally important factor to be addressed is the environmental concerns regarding the proposed site. This paper identifies the various factors that influence surveys related to engineering studies for early jackets.
This paper provides a critical offshore survey essentials checklist including sequencing of survey works in order to get maximum value for the Project Management Team that is necessary to be acquired during pre-engineering survey such that seabed surface, subsurface, environmental aspects and surface constraints are duly considered before arriving at the best optimal location for early jacket/s. The proposed guidelines also includes the prospect of expansion opportunities as part of future field development and will help to alleviate the need for any revisit to the site for survey, which would otherwise incur additional costs and cascading delays in the schedule for early production.
The critical survey guidelines here will cover in detail the requirements of acquiring geophysical, geotechnical, meteorological, oceanographic and environmental aspects including parameters that are required to be included in desktop studies about the site.
It is also essential to know the potential rig that is intended to be deployed at the location of interest such that number of rig approach boreholes can be determined based on the orientation of the tower and the planned rig. The geotechnical boreholes are a significant input to specialist studies such as Leg Penetration Analysis (LPA) and/or Site Specific Assessments (SSAs) reports as part of marine warranty location approval process.
The offshore survey essentials guidelines and sequence of survey works provided in this paper may be used as a ready reckoner for project engineering teams that are inclined to undertake early offshore jacket installation works.
Comparing Results of Different Tracer Technologies Application in One Well
Authors: Shestakov Dmitry , Galiev Marat , Badrtdinov Ilshat , Khamidullin Vadim , Ovchinnikov Kirill , Malyavko Evgeny 
Published: November 2019

Abstract
The present article highlights a new approach to solving objectives aimed at efficient and rational development of oil and gas fields based on conducted production logging of Kogalymneftegaz TME, LUKOIL-Western Siberia LLC horizontal wells with the application of marker-based technology Quantum PLT.
Well logging technology using markers is based on the application of quantum marker-reporters precisely indicating oil and water inflows. The placement of markers in the well implies two alternative technological solutions – application of marked proppant during MFrac or application of downhole cassettes with markers installed in the lower completion of the horizontal well. The advantages of the technology involve no necessity of well shut-in during downhole operations and the possibility to obtain an unlimited number of analytical data for a long period of time.
Marker-based technologies produced by different manufacturers differ in physical principles of operation, as well as in the methods of markers placement in the well or reservoir. The results of two alternative marker-based systems application in one well are shown in this article. This approach allowed us to compare the results and to evaluate the advantages and disadvantages of these two technologies. The well was completed by MFrac with the possibility of further ports control with the application of coiled tubing service. Each of five well intervals was equipped with two marker cassettes fixed on both sides of the MFrac port. Three months later MFrac with pumping marked proppant was performed on the well.
As a result of the world-first field application of alternative marker-based systems, valuable analytical material was obtained on the quantitative analysis of various markers, the performance of different polymers, the stability of the markers allocation in the formation fluid. The data obtained confirmed the character of the marked proppant pack washing out with the formation fluid in comparison with cassettes with markers.
Moreover, the efficiency of conducted stimulation was evaluated, specific horizontal well inflow profile types were identified, the degree of the reservoir management system impact on the inflow profile was evaluated.
It has been demonstrated, that received analytical data based on horizontal wells production logging enable addressing the issues of field digitalization at a totally new level, including: –visualizing recovery in hydrodynamical models;–control of hydrocarbon recovery, also by improving water flooding efficiency and better management of injection wells;–efficient planning of well intervention and stimulation techniques;–optimization of horizontal sections length and the number of MFrac ports;–adapting the relevant geological and hydrodynamic models considering analytical data related to production logging data, etc.
Efficient Trans-Dimensional Gravity Inversion of Salt Structures Offshore Abu Dhabi
Authors: Noei Emad Ghaleh , Dettmer Jan , Ali Mohammed , Lee Gyoo Ho , Kim Jeong Woo 
Published: November 2019

Abstract
This work investigates nonlinear inversion of gravity data to infer Infracambrian Hormuz salt structures offshore Abu Dhabi, UAE. A Bayesian approach with a trans-dimensional parametrization of the subsurface is applied that does not require regularization, resulting in more objective inversion results. The trans-dimensional parametrizations discretize the subsurface structure including the salt dome by an irregular grid of Voronoi cells. Both the number of cells and the cell coordinates are unknown parameters estimated from gravity data. The density contrast of the salt structures is assumed as known. The solution in Bayesian inversion is given by a large ensemble of parameter sets. Here, the trans-dimensional ensemble is obtained with the reversible-jump Markov chain Monte Carlo (rjMCMC) algorithm. Residual errors are parametrized by a full covariance matrix, which is estimated and updated as part of an iterative inversion scheme. Efficient rjMCMC sampling is achieved with parallel tempering. Inversion of airborne gravity anomalies illustrates well-defined Infracambrian Hormuz salt structures offshore Abu Dhabi, where the irregular grid spatially adapts to the data information and without the need to impose explicit regularization or fixed grids. Uncertainty estimates highlight salt dome extent. This study provides new insight into the existence and shape of oil reservoirs associated with the underlying salt structures.
Reservoir Description Insights from Inter-well Gas Tracer Test
Authors: Al-Qasim Abdulaziz , Kokal Sunil , Hartvig Sven , Huseby Olaf 
Published: November 2019

Abstract
Tracer technology has gained considerable attention recently as an effective tool in the reservoir monitoring and surveillance toolkit, particularly in IOR operations. Gas flow paths within the reservoir can be quite different from liquid (oil and water) flow path. This is primarily due to gravity override, and differences in density and relative permeability between the gas and liquid phases.
Inter-well gas tracer test (IWGTT) is a key monitoring and surveillance tool for any IOR projects. IWGTT should be designed and implemented to track the flow behavior of gas phase. The test generally entails injecting a small amount of unique perflouro-hydrocarbon tracers into the gas phase injectant stream. IWGTT have been conducted on a limited number of fields across the globe, and sample results of some will be presented.
The sampling frequency of the tracers from the producers should be designed carefully to collect the necessary data that will provide insights about the connectivity between the injectors and producers well pairs, gas breakthrough times ("time of flight"), and possible inter-well fluid saturations. Different fit-for-purpose unique tracers can be deployed in the subject injector(s) stream and their elution can be monitored in the corresponding up-dip producer(s).
In addition to reservoir connectivity and break-through times between injector and producer pairs, an IWGTT helps in optimizing WAG operations and production strategies for gas injection projects, improve sweep efficiency and ultimately enhance oil recovery. It can also be used to identify source of inadvertent gas leakage into shallow aquifers or soil gas, and help in the planning and placement of future wells.
This paper reviews the workflow and necessary logistics for the successful deployment of an inter-well gas tracer test. It will provide the best practices for designing, sampling, analyzing and interpretation of a gas tracer deployment. The paper also highlights the benefits of gas tracer data and their usefulness in understanding well interconnectivity and dynamic fluid flow in the reservoir. The results can be used to refine the reservoir simulation model and fine tune its parameters. This effort should lead to better reservoir description and an improved dynamic simulation model. The challenges associated with IWGTT will also be shared.