bluuebunny/crossref_metadata_2025 huggingface dataset:
Laboratory Evaluation of Formaton Damage Impact of Drill-In Fluid Lubricants in a Low-Permeability Sandstone Gas Reservor
Authors: Osode Peter , Otaibi Msalli , Bataweel Mohammed , Ammari Saleh , Himes Ron
Published: June 2014

Conventional lubricant products composed of different surfactant materials are required in water-based mud for drilling highly deviated and horizontal pay zone sections due to their lubricity associated with torque reduction and better penetration rate. Drill-in fluid (DIF) filtrate-induced formation damage in low-permeability gas reservoirs as a result of water blockage and reduced relative permeability to gas can be significant in view of the high capillary pressure associated with small pore throats. Formation damage risk assessment of the drilling lubricants utilization was therefore considered critical for a low-permeability gas reservoir development project.

Lubricant product evaluation experiments were designed to provide the production impairment potential measurements using Berea and Unayzah sandstone cores with a laboratory formulated DIF and base brine containing 3-4% lubricant by volume and to confirm fluid compatibility with divalent salt (CaCl2) brine. Fluid compatibility and emulsion risk was investigated using mineral oil as the representative formation hydrocarbon fluid. Core flood and dynamic filtration tests were carried out at an estimated bottom-hole temperature of 250 °F and pressure of 1,000 psi for the high-temperature reservoirs while the compatibility tests were carried out at room temperature. Filter cake removal tests were also performed by using high pressure, high-temperature filter press equipment and synthetic disks to determine filter cake removal efficiency with acid brine breaker fluid.

The obtained results from the laboratory study were integrated to evaluate and rank the lubricants based on their assessed formation damage risk. The test results showed that both lubricant return permeability and compatibility tests were important in selecting the best performance lubricant.

This paper discusses the experimental analysis of the formation damage potential of 12 commercially available water-based mud (WBM) lubricants. It also provides an insight into the formation damage (FD) impact of the drilling fluid lubricants on gas reservoir deliverability.
Pressure Pulse Generated by Valve Closure: Can It Cause Damage?
Authors: Zazovsky A. , Tetenov E. V. , Zaki K. S. , Norman W. D.
Published: June 2014

This paper takes a novel approach towards designing and managing the architecture and operating protocol of injection/production system. The shut-in valve positioning and timing of valve closure control the amplitude and frequency of pressure waves generated during shutdowns. The proposed approach provides the means for mitigating the negative impact of water hammer on the integrity of the near wellbore region and provides an idea of the intensity of any cross-flow issues. It is based on a comprehensive model that examines the fast wellbore transients (water hammer) generated by routine or emergency shutdown of injector or producer wells, which can also cause interaction with a near wellbore region of reservoir. The modeling handles the coupling of the conventional transient pipe flow hydraulics with the transient reservoir flow. The decompression wave created by shutting down an injector interacts with the near wellbore region that induces a transient flow back from the reservoir which creates a risk of mechanical damage by dislodging and transporting material with the fluid movement and even result in sand production. The compression wave created by shutting down a producer may induce repeated injection pulses. In both producing and injection cases, multiple cross-flow phenomena can be triggered between formation layers and wells interconnected within the injection or production system. The analyses of these transient phenomena help to potentially quantify the mechanical damage, which may be induced in near wellbore reservoir region, and assess the potential damage risk associated with produced solids.
Selectively Shutting Off Gas in Naturally Fractured Carbonate Reservoirs
Authors: Lozada Miguel , Torres Marcos , Gonzalez Marcela , Garcia Benjamin , Cortes Miguel , Milne Arthur , Miquilena Emilio , Perez Juan M.
Published: June 2014

In the Mexico marine region, gas breakthrough is common in naturally fractured carbonate oil reservoirs. Increasing the gas production reduces crude oil production, and eventually the wells become uneconomic and are shut-in in spite of the remaining recoverable reserves. A typical example is the Akal field, a large fractured 300-to 1000-m thick carbonate reservoir whose permeability varies between 0.3 and 5 darcy. The gas-oil contact zone moves by as much as 8 m/month as the natural gas and nitrogen gas from gas injection moves through the natural fractures and invades the oil zone. This condition results in production decline, reservoir pressure decrease, and oil remaining in the matrix.

Efforts to selectively shutoff the gas have been unsuccessful due to the low-reservoir pressure and high-permeability contrast. When pumping water-based fluids, the increased hydrostatic pressure causes the treating fluid to travel down the natural fractures and away from the gas cap. This condition led to abandoning the gas-invaded intervals and recompleting lower in the reservoir, leaving some recoverable reserves.

To selectively shutoff gas entry in fractured reservoirs, a stable foam-delayed crosslinked fluid was proposed for use by service company. The fluid with a high-foam quality (FQ) and low density rides over the crude and into the natural fractures/fissures, communicating with the gas cap. Once set, the fluid creates an impermeable seal with high-extrusion resistance.

The stable foamed fluid has been successfully used to selectively shutoff unwanted gas production in wells that have been, in some cases, shut-in for several years due to excessively high gas/oil ratios (GOR). Following the treatment, the oil production was restored to the same level as prior to the gas breakthrough.

The success of the initial campaign demonstrated that it is possible to restore the production levels of shut-in wells and recover otherwise lost reserves. This result has a very significant positive impact on the economics of operating the field. The current plan is to extend the use of the technique to other fields.
Filtering Out More Information from Laboratory Screen and Gravel Pack Tests
Authors: Fischer C. C. , Constien V. G. , Vining C. M.
Published: June 2014

Laboratory performance test methods for evaluation of the performance of screens and screens with gravel or frac packs have been relatively unchanged for several years. The small scale sand retention tests generally separate into two types depending on whether the tests are run at constant flow rate or constant draw down pressure. The data from the tests depends upon the laboratory running the tests and what information the client uses in the completion design. More useful information can be obtained by a more complete analysis of the formation material to determine bridging or fines migration tendencies based on ideal packing theory and pore size openings of the formation, gravel and or screen.

Attempts have been made at developing screen performance master curves based on formation particle size and screen opening as well as prediction of screen performance using analytical modeling techniques. Typically, formation samples used in lab testing have particle size distribution (PSD) by laser diffraction or for larger size distributions, conventional sieve stacks. Currently, the PSD information is used to relate the performance of the screens or gravel packs by relating the screen or gravel pack performance to the formation d10, d50 or d50/UC. Often this leads to good correlations for solids production and retained permeability. However, some formation distributions do not easily fall in to predictive performance curves. Often these formations have very small median sizes and are highly nonuniform.

Additional analysis of test data can answer questions such as whether solids production is at the interface of the screen or gravel pack or if fines will migrate through the formation material to continue to produce solids.

This paper will illustrate additional information that can be obtained from small scale tests.
Enhanced Water Flooding Sweep Efficiency by Induced Formation Damage in Layer-Cake Reservoirs
Authors: Zeinijahromi Abbas , Bedrikovetsky Pavel
Published: June 2014

Water channeling through high permeable layers during water flooding results in poor sweep efficiency. There are high costs involved in chemical methods of controlling mobility. Many laboratory studies evidence that injection of water with low salt concentration leads to significant decrease in the core permeability. In this paper the possibility of applying induced fines migration as an enhance oil recovery technique was investigated by modeling of the process. It was shown that the system of equations for water injection with induced formation damage is equivalent to polymer-flooding. It enabled applying polymer option of Eclipse black-oil simulator to model low salinity water flooding with induced formation damage. Investigation of the effect of induced formation damage on sweep efficiency during high salinity and low salinity water flood were the main aims of this study. Eclipse polymer flood model was used to model water injection with induced formation damage in a two layer cake reservoir. Analysis of modeling results showed that induced formation damage was favorable to sweep efficiency. Displacement of oil with low salinity water with induced formation damage resulted in up to 19% extra oil recovery. The sensitivity study showed that improved sweep during low salinity water injection was sensitive to heterogeneity, permeability reduction value, and slug volume. Introducing the permeability dependency of formation damage coefficient reduces IOR effects of induced formation damage during low salinity water flooding if compared with the case of constant formation damage coefficient. Several water flood scenarios with injecting different volume of low salinity water were modeled in order to determine the optimum low salinity slug volume. It was shown that injection of 0.5 PVI of fresh water with high salinity water drive results in similar incremental recovery if compared with continuous injection of low salinity water.
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

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

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

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

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

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

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

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

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

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

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

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

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.
Building Organisational Resilience - A Fit for Purpose Approach
Authors: Schack Clara Mohl , van den Essen Igor
Published: June 2014

Managing work related stress has become an increasing concern in society as well as in the oil and gas industry representing the second most prevalent work-related health problem, affecting 22% of workers in the European Union (EU-OSHA, 2009; WHO, 2010). Outplacing the traditional stress management approach there seems to be a tendency in practice as well as in research to address this growing concern with a proactive approach focusing on developing organisational resilience.

Based on above notion, it became obvious to an oil and gas company that a consistent approach targeting the matter was needed. In lack of both internal qualitative and quantitative data an interview study was conducted to investigate underlying factors of stress: job demands, control, role, support, relationships and change (HSE, 2009). 60 people across the organisational got interviewed on all levels distributed across four locations. Based on the relation between the two significant dimensions, job demand and control (Karasek et Thorell, 1990) it seemed apparent that stress did not represent a current issue for the organisation. However, the study pointed out 3 main concerns: 1) need for HR processes, 2) leadership capabilities and 3) cultural aspects.

The identification of the themes created an opportunity for a preventive approach introducing the resilience philosophy defined as the ability to bounce back and handle difficult situations in a flexible way as organization, leader and individual. Aiming to establish the organisational capacity targeting the identified gaps; the resilience program consists of three main streams addressing: the way we work (HR processes and policies), the way we lead (leadership competencies) and within the organisational environment (cultural support and awareness).

The program was rolled out centred around a global project community working up, across and down in the organisation in terms of delivering the specific deliverables of the program and embedded the resilience philosophy in the company culture.

The outcome has materialized in earlier return to work for employees suffering from stress, changes in leadership behaviour and support mechanisms as part of the workplace culture. This was obtained through a "fit for purpose approach" tailored to our specific organisational culture and needs.
Safety and Health Management Aspects for Handling Silica-based Products and Engineered Nanoparticles in Sequences of Shale Reservoir Stimulations Operations
Authors: Heidel Donna , Carson Kimberly , Baker John
Published: June 2014

The recent developments in the occupational safety and health management systems and assurance processes for the safe use of silica-based products, engineered nanoparticles, and nano-enabled lubricants will be discussed. Shale reservoir stimulations operations may result in workplace exposure risks. Recent findings of the occupational hazards and potential workplace exposure risks associated with silica-based products, engineered nanoparticles, and nano-enabled lubricants will be presented. The methods to assess risks and quantify exposures, and the appropriate engineering, work practice, and personal protective equipment will be discussed.

Exposure risks can be managed with a proper assurance process and equipment design. The value of including occupational health and safety considerations into the design of stimulations operations and the associated process and equipment to control worker exposure risks will be highlighted. This includes an ongoing assurance process that supports the re-assessment that is required as new information is developed about the hazards of these materials and new applications for these technologies. Ensuring worker safety and health during shale reservoir stimulations operations requires a systemic approach for identifying health hazards associated with both known and novel materials, and assessing and controlling exposure risks. Worker safety is essential to the successful shale reservoir stimulations operations technology development and adoption.
Is There a Net Benefit from Offshore Structures?
Authors: Fujii Toyonobu , Walls Anne , Horsfield Michelle
Published: June 2014

Understanding the utilisation of seafloor heterogeneity by different fish species is an essential prerequisite for the implementation of effective spatial management of marine ecosystems. The North Sea has long been a vital ground for the exploitation of natural resources, supporting one of the world’s most active fisheries as well as oil and gas exploration which has resulted in the construction of over 500 offshore platforms across the region. These facilities represent the major man-made structures installed on the seabed, adding substantial components of seafloor heterogeneity to the normally flat, featureless or soft sedimentary surroundings.

While there is a growing body of evidence demonstrating that a variety of fishes aggregate around these subsea features, it still remains unclear whether the fish individuals merely concentrate around the structures from surrounding areas or whether such effects can have beneficial effects for fisheries by facilitating net increase in fish stock sizes. The research presented here investigates the relationship between fish and the physical presence of artificial structures in order to elucidate the potential role of offshore oil and gas platforms in the ecology of fish populations in the North Sea.

To capture representative fish specimens closely associated with offshore platforms, seasonal fish sampling has been carried out since September 2010 at the BP Miller platform, a large steel jacketed facility in the Central North Sea. Although fishing from an operational platform is normally banned in the North Sea due to safety concerns, the Miller platform provides a unique opportunity for researcher to examine the possible effects of obsolete platforms on fish populations because it ceased production in 2007 and has since been used as a search and rescue helicopter base with minimum manning.

Results show that commercially important fish such as cod (Gadus morhua), haddock (Melanogrammus aeglefinus) and saithe (Pollachius virens) were the most characteristic species observed around Miller platform. However, there were marked changes in species composition and their relative abundances between seasons as well as years, suggesting highly dynamic nature of interactions between fish movements and the physical presence of the platform. Based on these results together with a range of studies from the relevant literature, implications for the ecological impacts of decommissioning on North Sea fish populations will be discussed.
Addressing Adaptation to Climate Risks in the Oil and Gas Industry
Authors: Landuyt William , Lee Arthur , Verduzco Laura , Castaneda Jeremy , Siveter Robert
Published: June 2014

Adaptation planning and implementation for managing climate change risks is rising up the agenda of governments and companies alike, broadening from a sole focus on mitigating greenhouse gas (GHG) emissions. There is a growing awareness of the need for adaptation as part of a balanced risk management strategy toward climate change. The objective of this paper is to explore the oil and gas industry’s awareness of climate change-related risks and appropriate responses, and efforts to incorporate them into an overall risk management framework. As a result of a recent IPIECA workshop we identified a few key observations regarding adaptation for the oil and gas industry: the oil and gas industry assesses a range of current and future risks from climate variability to their operations and infrastructure; impacts are local and projects are unique, hence assessments are being performed at the local level to design actions; uncertainty in climate variability and future scenarios suggests that flexible and robust engineering designs along with adaptive management practices will be critical for climate risk management. The paper is a mixture of author perspectives and ideas expressed at the workshop, and is structured to provide insight into the adaptation planning process, including: examples of climate risks identified by the oil and gas industry; the process of evaluating the risk posed by a potential impact; and examples of currently employed approaches to adapt and manage identified risks.
Facility Water Cycle Management in Diverse Conditions
Authors: Rowbottom Ron , Grinneiser Pascal , Cobb Jo Ann
Published: June 2014

The supply of potable drinking water, nonpotable processed water and ultimately wastewater disposal is a significant cost and logistical concern in many areas of the world. Water conservation and the demand for potable drinking water poses a daunting task for operating bases.

This paper outline challenges for facility management where water is a scarce resource through incorporating strategies and technologies for the water management cycle.

The sourcing of potable water is an issue where nonpotable ground water is the only alternative to high- cost tank and bottled water. Utilizing technologies to generate on-site potable water where potable water supply is restricted provides companies the opportunity to increase their available potable water supply, and provides corporate social responsibility benefits to the community.

Utilizing processed or nonpotable water, although more readily available, still poses issues for many locations because of arid conditions and water demand increasing logistics and cost of supply. This paper reviews strategies for sourcing and recycling technologies for nonpotable water to reduce impact.

The final aspect of water management includes the challenges with regard to disposing of processed grey water and black water from washrooms and other sources in locations where municipal waste water treatment facilities are not available. In such areas, removal and waste water costs can be significant. Additionally, companies must maintain environmental oversight to ensure waste water is properly managed to protect the environment and company reputation. The paper presents waste water disposal management strategies to control risk and costs, utilizing techniques and technologies that reduce water quantity and levels of pollutants in discharged water.

Case studies from facilities in Dubai UAE, Iraq, Brazil, and Algeria are presented to illustrate the process of holistic water management at service bases. The paper also introduces a water management tool developed to assess and quantify water management components, and the methodology to identify strategies and technologies for managing a facility’s water cycle. The approach encompasses the logistical, cost and social benefits of water management.
Learning & Benefits of Well-defined and Well-structured Topside Medical Support in the Offshore Drilling Industry based on 10 Years of Global Experience with a Large Offshore Drilling Contractor
Authors: Pelat Francois , Awotula Patrick
Published: June 2014

The offshore workplace is unique in that it concentrates heavy machinery and high-pressure operations in a self-contained and remote environment. It is hence an accepted - if not required - standard to maintain a clinic manned by a medical responder onboard the offshore drilling installations in order to handle routine ailments and provide the initial medical care and stabilization needed in the event of more serious emergency situations.

For a global drilling contractor with a significant number of overseas operations, the importance of enhancing the offshore medical response was early understood, leading it to develop, structure and launch the concept of Topside Medical Support (TMS).

The offshore medical personnel have been given round-the-clock access to a medical support line to provide all the guidance instructions and medical direction that may be required. A comprehensive set of medical protocols & procedures has been developed to support both offshore medical personnel and TMS teams. Several global and regional providers have been selected, trained and contracted to deliver TMS for the various Divisions and Business Units.

10 years of global experience have demonstrated the huge benefits of the concept in delivering a timely, appropriate and consistent medical response in the offshore workplace, in addition to preparing the way for further escalation whenever shore referral or international medical evacuation is required for the patient. The experience has also highlighted issues and challenges which have been addressed as far as is technically possible, as well as adding other features to maximize TMS effectiveness and benefits for the workforce, the employer and customers.

This paper will develop, analyze and review the above success story - which has now become requisite "best practice" for the offshore industry – and will also discuss areas for improvement.
An Overarching Strategy for Safety Critical Elements Assessment and Management
Authors: Cortina M. , Pavli E. , Antinolfi G. , La Rosa L. , Rainaldi I. , Petrone A.
Published: June 2014

Recent well known major accidents occurred in the Oil and Gas sector and their consequences on companies’ reputation and public image have dramatically confirmed that asset integrity enhanced safety performance and effective management of increased environmental risks remain one of the key challenges facing the industry today.

Investigation reports prove that Major Accidents typically materialize as a result of a combination of failures in processes, plant integrity and human behaviors. Processes, people and plant can be regarded as ‘barriers’ between the hazard and an incident. If they are all present and flawless, they can prevent a hazard becoming an incident.

Barriers which prevent Major Accident Hazards becoming accidents are called Safety Critical Elements.

Safety-critical elements (SCE) are defined as any parts of an installation (physical or non-physical elements), plant or computer programs whose failure will either cause or contribute substantially to a major accident, or the purpose of which is to prevent, or limit the effect of a major accident hazard (MAH). SCEs are thus generally designed to Prevent Detect Control Mitigate Rescue and Recover

This paper present the overarching strategy adopted and the requirements set out within our company for effective Management of Safety Critical elements.

The process by which SCEs are identified and performance standards set is fully described along with the strategy for their implementation within the company assets. The document also describes the verification scheme which is crucial to ensure that the integrity of SCEs is maintained and guidance is provided for the management of verification throughout the various stages of the asset lifecycle; it also deals with the management of change in relation to SCEs.

The paper concludes with considerations on the correct identification of roles and responsibilities for identification of safety critical systems, and the production, review and implementation of their Performance Standards during the whole asset life cycle: at the design stage for new facilities, or major modifications to existing facilities, until handover to the operating organization takes place; and at the operations stage.