bluuebunny/crossref_metadata_2025_split huggingface dataset:
Overcoming Wellbore Cleanup Challenges in Deepwater Wells in West Africa
Authors: Pietrangeli G. , Quintero L. , Jones T. A. , Benaissa S. , Menezes C. A. , Aubry E. , Poitrenaud H. , Furgier J. N. 
Published: June 2014

Abstract
Mesophase technology for wellbore cleanup and remediation in the drilling industry has been used in various oil fields to increase well productivity and injectivity. The majority of these applications include oil-based mud filter cake removal, nearwellbore remediation, and wellbore displacement.
The openhole wells completed with standalone screens in deepwater tertiary formations offshore West Africa have benefited from previous knowledge and experiences accumulated by the operator and the service company in the application of mesophase technology in other fields.
This paper discusses the field application of mesophase technology in several deepwater offshore fields in West Africa. Prior to the field application, the mesophase formulation was customized for the field conditions, such as temperature, fluid density, type of completion brine, and the specific oil-based mud. The customized formulation was evaluated to determine the regain of injection permeability, fluid compatibility, and the breakthrough time. Intensive tests were required to fine-tune the formulation to obtain the desired high injection permeability for the challenging field conditions.
Results from the laboratory and description of the field application are discussed and presented in this paper. The field applications data proved that, after placement of the mesophase treatment in the wells, diffusion of the treatment produced: (1) break-up of blocking solids from the completion screens; (2) removal of filter-cake residues; and (3) water-wetting of all solid surfaces. This cleaning treatment gave very good results in the production and water-injection wells.
Produced Water Re-Injection in a Deep Offshore Environment - Angola Block 17
Authors: Souilah R. , Brocart B. , Ourir A. , Onaisi A. , Pourpak H. , Ochi J. , Lescanne H. 
Published: June 2014

Abstract
Angola Block 17 is composed of several deep water offshore fields, producing oil, water and gas from unconsolidated Miocene and Oligocene sands. In these reservoirs, pressure maintenance and sweep efficiency are achieved by injection of desulfated sea water mixed with an increasing proportion of produced water. This reservoir management policy perfectly fits with Total's commitment to reduce discharges to the environment during its operations.
However, Produced Water Re-Injection (PWRI) comes with its own challenges, mainly because of well injectivity impairment linked to the presence of oil and solids in the injected water. Water treatment facilities are designed to meet water discharge specifications in terms of oil in water content and to remove solids. Yet it is difficult to accurately monitor the concentrations of solids present in the injected water at surface and when it reaches the reservoir wellbore interface.
Reservoir management (and more precisely voidage replacement management) strongly depends on the ability to monitor, analyze and manage the injectivities of wells. The objective of the present work is to describe the methods used to set injectivity index references and follow their evolution in time then to provide an insight into the injectivity decline and enhancement mechanisms.
Different injectivity decline models based on instantaneous proportion of produced water in the injected water or cumulative injected volumes of produced water and an injectivity enhancement model based on plastic shear strains which take place around the injector wells are also presented, discussed and compared to field data. In addition, methods for improving or restoring injectivity (injection of sea water batches or chemical products) are illustrated. Finally, a method for defining maximum allowable injection pressures for each well is described.
Short-Term Testing Method for Stimulated Wells--Field Examples
Authors: Kutasov Israel M. 
Published: June 2014

Summary
A new short-term testing (STT) method is developed and presented in thispaper. The STT method is based on a new semitheoretical analytical solution ofthe diffusivity equation for a cylindrical source and is used to describe thetransient buildup or drawdown pressures for stimulated wells. This solutiongives a good agreement with the results of a numerical ("exact") solution ofthe diffusivity equation. The analytical solution allows us to determine thebottomhole pressure (or pressure derivative) at linear flow andlinear-to-radial flow transition with high accuracy. For small values of time,the STT method gives a half-unit slope straight line (dimensionless pressuredrop is proportional to the square root of time), and for large values of time,the conventional equation for a radial flow can be obtained. The STT method canbe used for any values of flowing or shut-in time. For this reason, theprinciple of superposition can be used without any limitations. In thefollowing, we demonstrate application of the STT method for two acidized oilwells.
Evolution of Coiled Tubing Industry in Offshore Mexico over the Last Decade
Authors: Perez Jose del , Lopez Josue , Martinez Arturo , Solis Ulises , Deolarte Carlos , Huerta Martin , Franco Ernesto , Hernandez Daniel , Najera Raul , Hobson Bruce , Molero Nestor , Marin Marlon 
Published: June 2014

Abstract
Since its initial discovery in 1975, Offshore Mexico has been the most important oil producing region in the country, with production peaking at 2.8 MBOPD in 2003. However, since 2004, production has been quickly dropping and showing signs of field maturity; current production rate is at 1.8 MBOPD. Coiled tubing (CT) intervention had been typically required to keep production rates steady or even achieve improvement. In 2003, the operator and CT service provider formed a joint venture to put efforts to enable innovative solutions for addressing the challenges of this region.
The document discusses the various industry drivers that necessitated service improvements and technology introductions for successful CT well intervention over the last ten years. This paper focuses on the following areas:
Drilling and workover environment:
Extension of CT interventions in low-pressures to high-pressure wells (self imposed maximum potential wellhead pressures above 3,500-psi) Expansion of Offshore rigless interventions (from conventional operations on fixed platforms to boat-based operations) Extension of CT interventions from fixed-deck to deepwater floater operations
CT Applications
Conformance applications for water shut-offs and subsequent new perforations Logging interventions in long horizontal sections Real time downhole measurements during well interventions with CT equipped with fiber optic telemetry systems replacing downhole memory gauges
CT Equipment Improvements
Surface equipment improvements from conventional CT equipment to "latest generation" automated CT unit with active process control and safety systems
In summary, this paper presents an overview of the past, a review of the present and discussion of the anticipated future of CT services in the Offshore Mexico region in the context of short, medium and long term technical challenges are presented in several case studies.
A Versatile High-Expansion Hanger Device for Suspension of Downhole Devices during Performance of Critical Asset Diagnostics and Enhancement Methods
Authors: Zbitowsky Ron , Al-Murit Meflah , Denmon Michael , Gordon Scott , Babin Jacques , Mlcak Matthew 
Published: June 2014

Abstract
The rise in unconventional resource exploration relies on strategically placed sensors to record critical information during multiple forms of testing and reservoir enhancement techniques. The accurate data gained during the testing phases are what ultimately lead to the best flow regime design and successful optimization of the resources. New completion design or reservoir stimulation techniques are also effectively evaluated using data acquisition, aiding the development, refinement, and implementation of these techniques. Subsequently, suspension of the sensors in wellbores without decreasing flow can be challenging when introducing new techniques or modifications. Additionally, these flow rate conditions can prevent the determination of production at the most economically advantageous time and rate.
This paper examines difficulties associated with acquiring data that can exist because of new completion designs or exploratory methods tested as a means to optimize a resource’s economic viability. Solutions offered by a new high-expansion hanger that can be used to meet these difficulties are also discussed. The tool has been proven to be a durable and flexible solution for an increasing array of completion and reservoir enhancement techniques for many styles and types of well testing under varying pressures and conditions. The tool is available in a wide range of pipe sizes and types, enabling positioning inside liner sizes of larger inside diameter (ID) than that of the uphole completion tubing string within the wellbore. The high-expansion design also provides the assembly a generous bypass flow area, which helps increase the accuracy of the data received during flowing events.
Case histories are presented to illustrate the varying range of situations where the high-expansion hanger has been proven both a viable and valuable solution for reservoir analysis and optimization.
Using E-Line Conveyance in Multi-Stage Fracturing to Optimize Efficiency: A Case From Bakken, ND
Authors: Mann Rex , Schiavi Victor , Bukowski Rick 
Published: June 2014

Abstract
Multi-stage ‘plug-and-perf’ operations in the Bakken formation are conventionally performed using pump down wireline operations. However, when a restricted casing ID, coupled with road restrictions, strict budget and time constraints, and a long horizontal section prevented the use of conventional methods, an operator in North Dakota turned to e-line, tractor-based conveyance to get this $9M asset on line.
The operator needed to plug and perforate 26 zones from max depth at 21,740 ft up to the upper perforations at 11,830 ft to get the well on line swiftly. However, a 3.5 in. patch at 11,689 ft–11,709 ft meant the ID of the 4 1/2 in., 11.6# casing string was restricted, and thus the 4 1/2 in. plug could not be pumped in safely. Pumping the plug could cause it to set prematurely or get pumped off causing an expensive fishing job. Rig workover was deemed too time consuming due to the number of runs necessary and as a 2 in. coiled tubing (CT) string would only be able to reach about 17,000 ft, this option would have left 10 zones unperforated. To further complicate matters, spring thaw road weight restrictions were in place and the project was already over budget and behind schedule.
By turning to e-line tractor conveyance the 26 runs to ‘plug-and-perf’ were completed in just 14 days with no lost time. In addition, the patch was successfully negotiated, the plug set properly and the entire section was perforated. The swift and nimble nature of the e-line technology made it easy to overcome the logistical challenges and helped the operator with their timing and budget issues.
This paper will show why using e-line tractor conveyance was the right solution for this intervention where 146,608 ft were tractored with no lost time.
Improving Wellsite Systems Integration
Authors: Shields J. , Brackel H. 
Published: June 2014

Abstract
Automated systems are common in many industries, but remain a challenge for the drilling industry. Wellbores are drilled using an ad-hoc collection of equipment and services that are assumed to work together.
Standards for oil-industry information exchange have existed for many years but they are, in many cases, inadequate to convey the detail required for automation of complex processes such as real-time drilling control. Advances in information and communications technology have enabled other industries to implement new work processes and data flows, connecting disparate systems from multiple vendors in a safe, secure and reliable manner. Autonomous automobiles and aircraft are now a reality. Coiled tubing brings the potential for true real-time control of downhole equipment; however, it must function as part of an integrated system that includes surface equipment and sensors from a number of suppliers working in conjunction with the technical applications for directional well control and reservoir navigation.
In order to be widely adopted, integration solutions must be simple to implement and easily deployable – essentially an oil industry "plug-and-play" capability. History offers examples of previous oil industry standards that were over-engineered and too complex for simple and reliable implementation. Automation-enabling technology exists today, but oil industry-specific work must be undertaken to drive the adoption and implementation of these technologies in a fit-for-purpose manner. The focus must be to bring together the oilfield standards organizations to facilitate the definition and use of standards that will drive interoperability and automation.
Design Enhancements to Snubbing Unit Surface Equipment Delivers Improved Operational Efficiency and Safety
Authors: Sredensek Eric , Bruin Edwin 
Published: June 2014

Abstract
The gas caverns in Europe require dewatering strings with outside diameters (ODs) from 4.5 to 6 5/8 in. to be installed and removed under high pressure conditions. Snubbing units are typically used to perform gas cavern work on land. However, typical offshore snubbing units often take considerable time to rig up because they are not optimized to fully use larger crane capacities available for land applications.
Specialized fit-for-purpose snubbing equipment designed for land applications offers substantially improved efficiency and safety. This paper explores advances in snubbing unit designs that focus on Europe land application requirements.
Rigup performance greatly improves when modular preassembled equipment is delivered to the jobsite. Quick rig type snubbing units are rigged up with fewer crane lifts and fewer connections to make up, thus greatly reducing operation personnel exposure to rigup/rigdown hazards. Transport cradles are used to lift equipment safely from horizontal to vertical positions. Transportation is achievable anywhere in Europe without the requirement to apply for special overweight permits.
This paper also elaborates on safety system advances, such as slip bowl interlock system technology, to help ensure proper slip bowl operation and help prevent operator error, emergency egress systems, and improved pipe handling safety.
Corrosion Monitoring With EM Induction Tool in 3 Outer Casing Strings through a 7 Inch Chrome Production Tubing Scenario
Authors: Castaneda Claudio , Higuera Josue , Portela Fernando , Benavides Marcia , Valstar Dirk , Banerjee Shuvo 
Published: June 2014

Abstract
Impact of CO2 corrosion on well integrity is an issue in mature fields of Colombian foothill wells. Concerns in regard to corrosion of casing strings having access only through the existing 7" completion challenged the use of new technology to achieve both: log corrosion on outer strings and do not suspend the well to get a full column of fluid. Therefore, corrosion monitoring was performed through 7" chrome production tubing with a new Electromagnetic Scanning Tool (EMST), in a challenging scenario: shut-in well with 3 outer casing strings with a gas cap in the upper wellbore.
The job objectives were first to test the technology to detect metal loss from the outer casing strings as well as loss both inside and outside of production tubing (without pulling the production tubing) and second to establish a base line for future corrosion analysis after the immediate drilling rig intervention for sidetracking.
A careful candidate selection was performed based on criticality for CO2 corrosion, completion design, service years and operating status of the well including consequence analysis to get a pilot well for EM logging.
In production since 1998, the BA Y16 well was selected to be logged before a thru tubing deepening to reach two other reservoirs and further service conversion from oil producer into a gas injector well; the EMST was run in Q1 2013 and measuring the cumulative thickness up to three strings determining that no external corrosion was present in particular in the section of interest, also the high resolution image showed no presence of internal corrosion. Therefore, a successful operation was achieved meeting the proposed objectives with no HSE incidents and within budget.
This technology is proven and has become a solution for further wells where CO2 or bacteria damage has been evidenced including corrosion mapping through chromed and carbon steel in a single run avoiding the excessive costs related to pulling the completion to get access to the outer casing strings.
Increasing Lubricity of Downhole Fluids for Coiled Tubing Operations
Authors: Livescu Silviu , Craig Steven 
Published: June 2014

Abstract
The requirement for intervention operations in long lateral-reach wells continues to grow. In US, it is not uncommon to be asked to run coiled tubing (CT) in 10,000-ft laterals. In general terms, a 2-in CT typically has enough weight reserves to perform work to about half such a lateral. While increasing the CT diameter remains a theoretical option to improve reach, practically, it creates logistical challenges with both road transport and offshore crane lifting/deck loading limitations. Although fluid hammer tools and downhole tractors have extended CTs reasonable operational range significantly, they also increase circulating pressures and operational complexity. To reach a 10,000-ft lateral, the use of metal-on-metal lubricants will be required to work in conjunction with the other systems.
Obviously, the use of lubricants is not new. Typical real life results of current systems are about a 15-20% reduction in the coefficient of friction (CoF) from a generic 0.24 to 0.19. Occasionally, smaller CoF values could be obtained in the field. However, these actual results compare poorly to laboratory testing with a high pressure rotational friction test.
An extensive set of laboratory measurements was carried out using a linear friction measuring device to understand and quantify the mechanical, chemical, and thermal metal-on-metal wet frictional effects. Particular attention was paid to the synergy between lubricants and the other commonly circulated brines and fluid friction reducers. Other tests, such as regain permeability and aging tests have also been performed.
Arising from the trials is a new lubricant that reduced the linear CoF by approximately 40-60% (0.10 to 0.14) under downhole conditions. Friction reduction of this magnitude is expected to make it feasible to run CT in 10,000-ft laterals without the use of fluid hammer tools or tractors.
The paper details the new testing method, technical background of frictional drag, existing lubricant case histories, the new laboratory data, details of compatibility tests, and two new lubricant case histories.
Analytical Downhole Temperature Model for Coiled Tubing Operations
Authors: Livescu Silviu , Wang Xiaowei 
Published: June 2014

Abstract
The detailed modeling of temperature and friction for coiled tubing (CT) operations is especially important in extended-reach wells. Although the fluid flow through the CT and annulus, downhole temperature, and the CT mechanical friction inside the well are crucial during CT operations, a mathematical model that captures all these effects does not currently exist.
In a separate study, we propose a new temperature-dependent coefficient of friction correlation, based on an extensive in-house experimental data set. In the current study we implement this correlation in a thermal well flow model. The model includes transient single-phase mass, momentum, and energy balance equations for the CT and annulus. Heat exchange between tubing and annulus and between annulus and formation as well as heat generated by CT mechanical friction while sliding inside the well are included in the model. Frictional pressure drops due to the fluid flowing downwards through the tubing and upwards through the annulus are also included in the momentum equations. The formation temperature is assumed to be geothermal. Although the model is aimed specifically at CT operations, it can easily be extended to other applications where thermal multiphase well flow in tubing and annulus is important.
We proceed by first presenting two analytical solutions for tubing and annulus temperature under various assumptions (similar solutions have been previously obtained for drilling operations). We then describe the use of one of these solutions, which allows for space-dependent fluid density and velocity and time- and space-dependent temperature inside the tubing and the annulus. The analytical model is verified against the corresponding numerical model that solves the full mass, momentum, and energy conservation equations and is validated against a Distributed Temperature Sensing (DTS) field case. Close agreement is obtained for the cases presented. A synthetic case that shows the effect of several key downhole parameters on tubular and annular temperature is also presented. We show that temperature distribution inside the well is important for best prediction of an average coefficient of friction for the entire well. For instance, the generic coefficient of friction of 0.24 that is currently used in the planning of CT operations does not apply for similar CT strings in wells with different downhole temperatures. The overall procedure is therefore very well suited for use in thermal simulation of CT operations.
Prevention of Heart Attacks and Other Cardiovascular Diseases in the Oil and Gas Industry
Authors: Barbey Alex , Mika Frano 
Published: June 2014

Abstract
In consideration of the prevalence of cardiovascular disease and its effects on the workforce in the oil and gas industry, the OGP-IPIECA Health Committee (OIHC) set up a Cardiovascular Risk Factors Group in 2011 to review the risk factors for cardiovascular diseases (CVDs) and their related health consequences and to propose innovative solutions that the oil and gas industry could implement. The outcome was the 2013 publication of "Prevention of Heart Attacks and Other Cardiovascular Diseases: A Guide for Managers, Employees and Company Health Professionals." The document provides basic guidance on the main types of CVDs and their causes and symptoms, looks at some implications of CVDs for the oil and gas industry, and offers strategies and improvements for implementation to help reduce the number of CVD-related deaths.