bluuebunny/crossref_metadata_2025 huggingface dataset:
High-Speed Field Development Planning in the Presence of Uncertainty and Risk Through the use of Constrained Numerical Optimization and Analytical Simulation
Authors: Tilke Peter G. , Bogush Alexander , Bolanos Nelson , Corbett Chip , Kolupaev Aleksander , Grove Greg P. , Spath Jeff , Thambynayagam R. K. , Wu Jinyong , Zhou Wentao
Published: June 2014

We present a framework that automatically generates an optimal well placement plan (WPP) based on a reservoir model. The proposed WPP comprises wells, their completions, and the drilling schedule. A suite of high-speed computational components allows this WPP to be generated in minutes. Greenfields and brownfields are supported. Brownfields require consideration of historical and ongoing production by existing wells along with collision avoidance when proposing new wells. The proposed wells can be producers or water injectors with vertical, deviated, or horizontal geometries. Different development strategies can be investigated that allow targets to be driven by geology or standard pattern such as an inverted five-spot. In addition to proposing new wells, existing wells may be sidetracked or recompleted.

Optimization of the WPP uses a constrained downhill simplex approach. During a trial, WPPs proposed by the optimizer in earlier trials are extrapolated to propose a new WPP. The proposed WPP must satisfy a wide range of geometric, operational, contractual, and legal constraints on the surface and in the overburden and reservoir. Collision and hazard avoidance computation uses a geocomputation topology approach. When a feasible WPP is discovered, the production forecast is computed using a high-speed semi-analytical reservoir simulator, which renders a result within a few seconds, using an analytically computed pressure and explicitly computed saturation. This reservoir simulator is fully three-dimensional and discretizes the reservoir to represent the underlying heterogeneity. In addition to recovery, the framework allows a variety of objective functions including net present value, return on investment, and profitability index. Optimization in the presence of subsurface uncertainty is considered by using an ensemble of reservoir models. A proposed WPP will then have an uncertainty in the forecast value. For a specified aversion to risk, a conservative or aggressive WPP can then be optimized.

The framework has been applied to a variety of workflows. These include rapid evaluation of the potential of different waterflooding strategies, drilling multiple infill wells from existing platforms, and identification of sidetrack candidates in mature fields.

This new framework has many applications in the field development planning workflow, including rapid screening of multiple fields and development scenarios. The most promising scenarios can be used with detailed numerical simulation for further validation.
Field Implementation of a Relative Permeability Modifier during Stimulation Treatments: Case Histories and Lessons Learned After More than 3,000 Treatments
Authors: Vasquez Julio , Eoff Larry
Published: June 2014

Relative permeability modifiers (RPMs) have been used by the oil and gas industry for more than two decades to selectively help reduce excessive formation water production. RPM systems are appealing to operators because their deployment simplicity requires no zonal isolation (i.e., bullhead-type treatments). This paper discusses the application of a novel RPM system that was originally developed for water control; however, its application was extended to hydraulic fracturing, acid stimulation, overbalanced workover interventions, and waterflooding.

This RPM system is based on a hydrophobically modified water-soluble polymer that, once adsorbed to the surface of the rock, selectively reduces the effective permeability to any aqueous fluid with little or no damage to oil or gas production in both injection and production modes. The hydrophobic modification to the base polymer chain adds unique associative properties to the system that allow multiple novel applications. The following applications are discussed in this paper: (1) the combination of the RPMs with hydraulic fracturing stimulation treatments in intervals previously bypassed because of their proximity to mobile water zones; (2) the combination of RPMs with acid (matrix and non-matrix) stimulation treatments used as a diverting and water control agent; (3) RPMs during overbalanced workover interventions (i.e., wellbore cleanouts, tubing-conveyed perforating (TCP), and gravel packing) used as a fluid-loss control agent; and (4) RPMs during waterflooding for improved profile modification as a diverting agent. Because this RPM does not affect hydrocarbon permeability, this system does not require the use of breakers or a cleanup stage, eliminating possible negative impacts on post-stimulation well productivity.

To date, more than 3,000 treatments have been performed with this RPM system. This paper discusses the RPM performance testing and a wide variety of case histories detailing the applications described in different types of reservoirs and wellbore completions.
Reducing the uncertainty of static reservoir models: implementation of basin-scale geological constraints
Authors: Weltje Gert Jan , Dalman Rory , Karamitopoulos Pantelis , Sacchi Quinto
Published: June 2014

We propose a new workflow for building static reservoir models of siliciclastic fluvio-deltaic systems. The proposed strategy requires a process-based stratigraphic simulation model which incorporates a reservoir-scale alluvial architecture module nested within a low-resolution basin-scale (sequence-stratigraphic) model. The basin-scale model is run with the intent to approximate large-scale basin-fill properties (based on geological/geophysical background information about palaeotopography, sea level, sediment supply, subsidence, and so forth). Subsequently, the model may be stochastically optimised by dedicated post-processing software to mimic sub-grid (reservoir-scale) properties of selected parts of the basin fill. This approach allows us to narrow down the range of possible scenarios (realisations) from the outset, which results in more reliable uncertainty estimates associated with reservoir models. Pilot studies suggest that the improvement of geological credibility of stochastically simulated fluvial reservoir models may go hand-in-hand with a significant reduction of the computational effort of inverting basin-scale (process-based) stratigraphic forward models. The implementation of geological constraints on object-based models is expected to improve estimation of sand-body connectivity and dynamic reservoir behaviour, and will therefore contribute to reduction of the non-uniqueness in current static reservoir models. Furthermore, the uncertainty associated with each basin-scale parameter can be propagated all the way through to reserve estimation. The partitioning of the overall uncertainty into contributions at the basin and reservoir scales may be quantitatively assessed, and the information content of all available data may be quantified.
Opportunity of Enhanced Oil Recovery Low Salinity Water Injection: From Experimental Work to Simulation Study up to Field Proposal
Authors: Callegaro Chiara , Bartosek Martin , Masserano Franco , Nobili Marianna , Parracello Valerio Parasiliti , Pizzinelli Corrado Sebastiano , Caschili Alessandro
Published: June 2014

Low Salinity waterflooding is an emerging Enhanced Oil Recovery technique in which the salinity of the injected water is controlled to improve oil recovery vs. conventional, higher salinity waterflooding. The objective of this work is the evaluation of low salinity water injection as EOR process in an on-shore field in West Africa. The field is heavily faulted and highly heterogeneous. The reservoir fluid is light crude oil; very different productive behaviours are present in the field.

An experimental work was performed to verify the effectiveness of the process and make deeper investigation about the chemical and physical mechanisms involved in low salinity water injection. Core flooding experiments on reservoir porous media were carried out, giving promising results in terms of matrix additional oil recovery with low salinity waterflood.

Furthermore, a simulation work to predict the benefits in the field was executed. Core experiments were reproduced using a wettability change model to obtain low salinity water parameters, the salt-dependent relative permeability curves. The process was scaled up to a fine sector model, calibrated on historical production data, representing the area of interest for low salinity water pilot. Simulations of low salinity water injection were run in different forecast scenarios and additional recovery was compared with sea water injection.

In order to evaluate the global effect of low salinity water injection as EOR process, all the aspects were taken into consideration, decrease in residual oil saturation, permeability reduction, expected sweep efficiency on effective reservoir matrix volume. The experimental and simulation results were used for an economical feasibility study for a desalination plant in the field to reduce the salinity of current injected sea water.
Multi-Scale Simulation of WAG Flooding in Naturally Fractured Reservoirs
Authors: Elfeel Mohamed Ahmed , Al-Dhahli Adnan , Geiger Sebastian , van Dijke Marinus I.
Published: June 2014

Naturally Fractured Reservoirs (NFR) contain a significant amount of remaining petroleum reserves and are now being considered for water-alternating-gas (WAG) flooding as secondary or tertiary recovery. Reservoir simulation of WAG is very challenging even in non-fractured reservoirs because a proper set of saturation functions that describe the underlying physics is vitally important but associated with high uncertainty. For NFRs, another challenge is the upscaling of recovery processes, particularly the fracture-matrix transfer during three-phase flow, to the reservoir scale using dual-porosity or dual-permeability models.

In this work, we approach a solution to this challenge by building models at various scales, starting from pore-scale to an intermediate scale then to the reservoir scale. We show how pore-network modelling and fine grid modelling where the fractures and matrix are represented explicitly can be used to increase the accuracy of numerical simulations at the field-scale in order to predict recoveries for NFR during WAG. We study the sensitivity to WAG design parameters as well as the impact of matrix wettability on recovery. We also compare the fine grid model with an equivalent dual-porosity model.

Simulation at an intermediate scale showed at least 10% absolute change in recovery due to the choice of the empirical three-phase relative permeability model. In fine grid simulation with physically consistent pore-network derived three-phase relative permeability and capillary pressure, injected water and gas are predicted to displace each other, leaving oil behind, therefore reducing WAG efficiency. For this case, empirical models over-estimate recovery by 25%. Classical dual-porosity model over-estimates recovery during the early WAG cycles, and fails to adequately match recovery of the fine grid simulation.

Our multi-scale simulation approach identifies important factors and uncertainties when considering WAG flooding in NFR. It provides a methodology through which WAG recovery can be estimated using available technology while preserving the pore-scale physics for three-phase flow, which are crucial to making reliable forecasts at the reservoir scale.
Experimental Investigation of Polymer Flow through Water- and Oil-Wet Berea Sandstone Core Samples
Authors: Hatzignatiou D. G. , Moradi H. , Stavland Arne
Published: June 2014

Polymer behavior under different wettability conditions is investigated through coreflood experiments conducted on cores with different wettabilities, but of the same pore structure. Berea core samples are used in the experiments with the wettability of one core altered to oil-wet conditions. A series of polymer and water floodings are performed with the polymer properties in porous media calculated and the formation wettability evaluated based on the measured laboratory data.

The effect of wettability on polymer behavior in porous media is the main focus of this work. In the first part of this study, the bulk rheology of a hydrolyzed polyacrylamide (HPAM) dissolved in two synthetic brines of different salinities is studied. A Carreau-type model is fitted on the experimentally measured data and the effect of salinity on the rheological properties of the HPAM polymer is investigated. A power-law model is also developed for the same experimental data.

For the core flooding experiments, a new setup is implemented in which, instead of measuring manually the core effluent concentrations during the polymer flooding, a capillary tube is connected to the core outlet. Using the notion of the intrinsic viscosity, a formula is derived to estimate the polymer concentration from the pressure drop recorded across a capillary tube mounted at the core effluent. In addition, basic properties related to polymer flow in porous media, such as polymer adsorption, inaccessible pore volume, and apparent viscosity are evaluated for the cores and both wetting conditions.

From the bulk and coreflood experiments conducted in this work, several important findings are reported. The examined polymer solutions display both upper Newtonian and shear thinning flow regimes in our bulk rheology investigation, with the effect of brine salinity on polymer viscosities to be significant. From the core flooding experiments, both polymer shear thickening and degradation flow regimes are observed on the water-wet core sample. The oil recovery factors and oil recovery vs. time profiles for the Berea oil- and water-wet core samples vary significantly and in accordance to the expected wetting conditions of the cores. The Berea water-wet core has the highest value of polymer retention, inaccessible pore volume (IPV) and permeability reduction factor (RRF) compared to the oil-wet core sample. The results displayed in this work confirm that the formation wettability has a significant effect on the polymer behavior in porous media.
Dynamic Matrix-Fracture Transfer Behavior in Dual-Porosity Models
Authors: Su Shi , Gosselin Olivier , Parvizi Hadi , Giddins Marie Ann
Published: June 2014

A dual-porosity simulation model is a coarse upscaled representation of a naturally fractured reservoir. Fluid transfer between the matrix and the fracture is described by a matrix-fracture transfer function, which is dependent on a shape factor. However, the basic formulation assumes pseudosteady-state conditions and requires modifications to capture transient effects. This paper describes the use of a dynamic shape factor for matrix-fracture transmissibility with block-to-block effects to improve the simulation of oil recovery in a dual-porosity model.

A simple fine-grid single-porosity model is compared with a coarse-grid dual-porosity equivalent for a gas-oil system under gravity drainage without capillary effects. A time-varying relationship between the shape factor and the matrix oil saturation is derived by numerical analysis. Vertical block-to-block connections are included in the model to match oil reinfiltration from the fractures to the matrix. The saturation-dependent shape factor correlation is generalized for other matrix block sizes. An improved match to fine-grid recovery is achieved in the dual-porosity simulation through use of a dynamic transfer function and block-to-block effects. The methodology is shown to be appropriate for a range of matrix sizes and, with different relative permeability curves, for the matrix blocks. However, attention must be paid to the relationship between simulation grid cell size and geologic matrix block size. Additional study of block-to-block flows is recommended to further improve the predictive capability of the model.

Fast and accurate simulation of flow in naturally fractured reservoirs is often difficult to achieve. The standard matrix-fracture transfer model is unsuitable for many situations. In the example presented here, we show how a coarse simulation model can be used effectively to capture variations in dynamic matrix-fracture transfer behavior over time for a specific case. The approach can be generalized and applied to similar studies.
Extension and Verification of a Simple Model for Vertical Sweep in Foam Surfactant-Alternating-Gas Displacements
Authors: de Velde Harsenhorst R.M.. M. , Dharma A.S.. S. , Andrianov A.. , Rossen W.R.. R.
Published: June 2014

Foam is a promising method to improve sweep in gas-injection enhanced-oil-recovery (EOR) projects. For cases in which well-to-well distances are large, the question arises whether foam can prevent gravity segregation over these distances. For such cases, theoretical studies suggest that the best process is to inject one large slug of surfactant followed by one large slug of gas. Shan and Rossen (2004) present a simple model for such a process that provides an initial assessment whether foam can prevent segregation over large distances. They did not extend their calculations to the large distances between wells in some potential applications, and they treated only the case in which vertical permeability kv equals horizontal permeability kh. Here, we extend the model to cases of kv < kh. We derive an analytical solution for the limit as kv approaches zero, which could serve as a quick first estimate of feasibility for other cases. Surprisingly, the model predicts that gravity segregation is worse as kv decreases; the reason is that, with large kv, foam pushes downward in response to the pressure difference across the tilted foam front.

We illustrate the use of the model with an example from a North Sea field, in which the issue was whether foam could prevent gravity segregation over a distance of several kilometers. The simple model said this was feasible, and more-detailed 2D cross-section simulation then confirmed that segregation was insignificant over an interwell distance of 6 km.

One can fit the model parameters to foam parameters derived directly from laboratory data. We illustrate with a model fit by Rossen and Boeije (2013) to data of Persoff et al. (1991), a fit specifically designed for a hypothetical surfactant-alternating-gas (SAG) application. The fit of simulations to the simple model is closer than in the North Sea example, and the prediction that sweep is better with kv = kh than for kv = 0 is confirmed. Moreover, the idealized model predicts the injectivity in this case very accurately.
Smart Learning from Past Data Yields 50% Incremental Oil Production
Authors: Pairault S. , Daudin R.
Published: June 2014

This paper presents a novel methodology for re-developing mature fields and increasing their production and reserves. It has been successfully applied to Butte Voluntary Unit, Canada, where it yielded a 50% production increase. Such upside results from a rational and massive search for the best re-development plan. The method uses a reliable production forecast tool specifically developed and calibrated for the given field. This is based on a smart learning process from historical production data, constrained by reservoir and well physics. The tool is not only reliable, it is also very fast: any given production forecast can be played within seconds. A powerful search engine is used to generate, select, adjust, and compare 100,000s potential field development plans ("scenarios"). Those are ranked for best Net Present Value, within different sets of financial and technical constraints ("strategies").

The full process was successfully applied to Butte Voluntary Unit, a water flooded mature field in Western Canada. A comprehensive range of strategies was explored, enabling robust decisions with respect to future oil price assumption, and ranking investment priorities. After playing 600,000 different possible production scenarios, a financially optimized re-development plan was identified involving four conversions out of 69 candidates, and the drilling of four new infill wells out of 20 possible sweet spots, as well as an upgrade of the field injection capacity.

This re-development plan was actually implemented on the field and became operational during the summer of 2011. Since then, oil production has soared as planned and incremental 5 year-reserves about 50% above the baseline are being demonstrated. This project illustrates that historical production data of mature fields have plenty to tell, and demonstrates how they can be smartly used to engineer the right re-development path and unlock considerable upside with controlled investment and low risk.

Mature fields are gaining increasing importance within most oil & gas companies’ portfolios. Relying on several field proven successes, the technology presented in this paper is becoming a reference tool for re-developing mature fields.
Multi-Rate Mass-Transfer Dual-Porosity Modelling Using the Exact Analytical Solution for Spontaneous Imbibition
Authors: Maier Christine , Schmid Karen S. , Ahmed Mohamed , Geiger Sebastian
Published: June 2014

Multi-phase flow in carbonate reservoirs, which hold about half of the world’s remaining oil reserves, is strongly influenced by fractures present in the geological formations. Fractures are often the main flow conduits, leaving most of the oil behind in the low permeability rock matrix, and cause early water breakthrough. An accurate characterization of fracture flow and fluid exchange between fracture and matrix is needed to forecast oil recovery and optimise production in fracture-dominated and fracture-assisted reservoirs.

Dual-porosity simulations are traditionally used to model naturally fractured reservoirs. However, the classical dual-porosity models miss some key physics of fracture – matrix fluid exchange: (1) They tend to simplify mass transfer due to spontaneous imbibition since they typically cannot include arbitrary petro-physical properties due to e.g. wettabilities, viscosity ratios, initial water content, etc. (2) They cannot account for the fact that matrix blocks within a single simulation grid cell have various sizes and permeabilities, giving rise to different transfer rates, which should be captured by a distribution of transfer functions in each grid cell.

In this paper we present a novel multi-rate dual-porosity model. It is based on an unstructured finite element – finite volume technique, which solves the governing equations for two-phase flow fully implicitly. This allows us to represent complex large-scale geological structures (e.g., non-orthogonal faults and fracture corridors) accurately while small-scale diffuse fractures are modeled with an improved dual-porosity approach. Until recently, calculating the mass transfer between fractures and matrix blocks due to spontaneous imbibition for arbitrary petro-physical and fluid properties exactly was not possible because a general and exact transfer rate for arbitrary petro-physical and fluid properties was not known. In our new dual-porosity model we compute fracture-matrix transfer using the only known analytical and general solution of the Darcy equation including capillarity. This provides us with a generalised transfer function for arbitrary wettability, viscosity ratios, rock types, initial water content and boundary conditions. Each reservoir simulation grid block can contain multiple of these generalised transfer functions to model different matrix permeabilities and/or matrix block sizes present at the sub-grid scale.

Using a series of proof-of-concept simulations, we show that the difference in oil recovery using a standard single-rate dual-porosity model and our new multi-rate dual-porosity model cannot be neglected. This demonstrates that our proposed model with the generalised transfer function predicts oil recovery more accurately compared to a classical dual-porosity model.
Miscible and Immiscible Gas Injection for Enhancing of Condensate Recovery in Fractured Gas Condensate Reservoirs
Authors: Taheri Amir , Høier Lars , Torsæter Ole
Published: June 2014

Gas condensate reservoirs usually exhibit complex flow behaviors because of accumulation of condensate in the reservoir and two-phase flow of gas and condensate when the reservoir pressure drops below the dew-point. In some complicated geological systems like naturally fractured reservoirs, these complex behaviors will be more. In these systems, pressure drop response propagates in the fracture network and all the matrix blocks surrounded by fractures are influenced by pressure drop in the wellbore. This causes accumulation of large amount of condensate in the matrix blocks entire the reservoir when the pressure drops below the dew point. Usually, the accumulated condensate saturation in the matrix blocks of fractured reservoirs is lower than the critical condensate saturation that causes trapping of large amount of condensate in the matrix blocks. So selection of an efficient EOR scenario for recovering this trapped condensate is important.

In this paper, a single matrix block surrounded by fractures is used to study the performance of a fractured gas condensate system in natural depletion, miscible and immiscible gas injection. C1, N2, CO2 and stock-tank gas composition are considered as injection gases and their miscibility with condensate is studied. Also some sensitivity analyses were performed on different parameters for more accurate investigation about the effects of different parameters on performance of the fractured system in different production scenarios.

In both miscible and immiscible gas injection scenarios, the timing for injection and injection gas composition are two key parameters. In miscible gas injection case, miscibility is the main mechanism for condensate production, while in the case of immiscible gas injection scenario, vaporization of condensate by injected gas is the more efficient mechanism for condensate recovery. Gas-gas miscibility mechanism is more efficient in comparison to gas-condensate miscibility in miscible gas injection and vaporization in immiscible gas injection scenario.
The H2STORE Project - Experimental and Numerical Simulation Approach to Investigate Processes in Underground Hydrogen Reservoir Storage
Authors: Ganzer L. , Reitenbach V. , Pudlo D. , Panfilov M. , Albrecht D. , Gaupp R.
Published: June 2014

The objective of the H2STORE ("hydrogen to store") project is to investigate the feasibility of storing hydrogen produced from excessive wind and solar power in porous geological formations as well as the investigation of in-situ methane generation processes. H2STORE is a three-year, joint research project of the universities Jena and Clausthal and the national research centers GFZ, Potsdam in Germany and CNRS, Nancy in France started in 2012. The project is supported by international industrial partners and funded by the German national research program on "energy storage".

So far, several studies on H2 storage in salt caverns have been published and pilot projects are already established (e.g. in the U.S. and U.K.). Hydrogen storage in porous geological formations, however, has received only limited attention in the past. In contrast to salt caverns, porous formations could potentially provide very high storage capacities. Several concerns like the high hydrogen diffusivity have to be investigated as well as the potential reactions of injected hydrogen, formation fluids, and the storage complex. The aim of the project is to evaluate the feasibility of hydrogen storage in converted gas fields by comprehensive investigation of geo-hydraulic, mineralogical, geochemical and biological processes, gas mixing processes, caprock integrity and fluid transport properties of the reservoir rocks during the storage of hydrogen in porous rock formations.

The hydrogen impact on fundamental reservoir properties and mineralogy will be investigated experimentally as well as geochemical and gaseous phase mixing numerical simulations are included in the project activities of H2STORE. Industrial partners will provide site-specific rock material and experimental facilities for treatment of the samples under reservoir conditions have been designed and built as part of the research program.

The experimental results will be included in numerical reservoir simulation work comprising:

(a) Modeling of hydrogen propagation in the subsurface reservoir formation supplemented by its mixing with the residual gases, (b) Simulation of the geochemical reactions of gas mixtures with rock minerals, organic substances and formation water, and (c) Modeling of coupling of bio-dynamic processes and the processes of reactive transport in porous media. The simulations shall enable the transfer of experimental results from the laboratory to the field-scale and help formulating requirements on hydrogen storage in converted gas fields.

An overview on the concept, objectives and goals of the collaborative work will be presented, which may serve as an impulse for ongoing investigations on hydrogen and energy storage in porous underground rocks.
Characterization of Methane Emissions from Key Sources in the Natural Gas Production Sector
Authors: Ritter Karin , Emmert Amy , Shin David , Smith G. Reid , Lev-On Miriam , Shires Terri
Published: June 2014

Natural gas comprises almost one-fourth of all energy used in the U.S. with growing importance in the global energy mix. New production techniques, including those involving hydraulic fracturing, have enabled access to expanded energy resources and to increased natural gas based power generation, which has been credited with reducing greenhouse gas emissions in the U.S. However, in 2011, the U.S. Environmental Protection Agency introduced new calculation methods for gas wells - based on limited data - causing calculated emissions from natural gas systems to more than double in the U.S. national greenhouse gas inventories for 2009 and 2010 (submitted to the United Nations in 2011 and 2012 respectively).

To provide better data about natural gas systems, the American Petroleum Institute (API), in collaboration with America’s Natural Gas Alliance (ANGA), undertook a survey of U.S. natural gas production companies resulting in a rich data base from over 90,000 natural gas wells widely distributed among different producing regions in the U.S. This paper analyzes key findings of the API/ANGA study regarding methane sources pivotal to EPA’s assessment, including completions, workovers and gas well liquids unloading operations.

While the API/ANGA findings indicate significant potential overestimations in EPA’s assessment, they also confirm the importance of understanding the key activities and conversion factors that impact the estimation of methane emissions from natural gas production. Although improving the greenhouse gas emission estimation methods may take time, a more nuanced analysis is essential for informing public debate and facilitating decisions on natural gas use and its role in mitigating overall greenhouse gas emissions.
What Value Does HIA Offer to the O&G Sector in Europe?
Authors: Phillips Callie , Cummins Claire
Published: June 2014

Health Impact Assessments (HIAs) have been traditionally utilized in the context of less developed countries where communicable diseases are prevalent and where major projects, such as those related to the extractives industry can have a significant impact. However in a European context impacts from projects are less likely to result in major negative health impacts in part due to the health protection and regulatory context that prevails in the EU. This may call into question the need to conduct HIAs in a European context.

Drawing on project experience and publicly available research, this paper presents a case for HIA to be undertaken in a European context and demonstrates the value it offers in aiding our understanding of the way in which project impacts can affect public health. The paper will identify the benefits of the HIA in providing a rational framework and process for the identification and evaluation of health impacts that are relevant in the socioeconomic, environmental and cultural context and for developing evidence-based recommendations to inform health protection decision-making. The paper will conclude that whilst the health profile may vary across regions and global geographies, human health and well-being can be influenced by positive and negative effects of major projects. Health impact assessment is a requirement of projects funded by the International Finance Corporation (IFC) and of the Equator Principles and guidance has been produced by IPIECA for its members. Outside the oil and gas sector HIA is also widely practiced by the mining sector.
Journey to Zero: Aspiration Versus Reality
Authors: Ritchie Norman W
Published: June 2014

The E&P industry has embarked upon a "Journey to Zero" in which SPE has taken a leading role. While "Zero" is a noble and worthy philosophical goal, this paper describes several practical challenges that exist in turning this aspiration into reality with respect to defining, measuring, attaining and sustaining such a performance. A realistic and defensible definition of "Zero" is offered that bridges the gap between aspiration and operational reality which potentially has application in all organizations on a "Journey to Zero".
Best practice in managing biodiversity and ecosystem service issues in any operating environment
Authors: Pavanel Elena , Marconi Michele , Nucci Maria Estella , Palliggiano Diana , Pedroni Paola Maria
Published: June 2014

Oil & Gas operations occur in a range of environments with different degrees of ecological sensitivities. Operations are dependent on natural resources that biodiversity and ecosystems provide, and may also cause impacts both in the short and long term.

The Oil & Gas industry has long recognised the importance of managing interactions of its activities with the natural environment and the need to integrate biodiversity and ecosystem services (BES) into existing environmental management practices throughout the project life cycle. This is key to ensuring business continuity, the sustainable use of nature and access to new resources, which are increasingly located in sensitive, remote environments.

Over the past decade eni e&p Division, working in partnership with the leading international conservation NGO Fauna and Flora International, has developed company best practice for a timely and effective BES management within its global operations. This has been field-tested through pilot BES assessments and action plans in onshore and offshore sensitive environments (Italy, Ecuador, Norway, Alaska, Congo and Pakistan), and has led to an improved environmental management system.

The application of ecological science, emerging conservation concepts and international best practices combined with the knowledge gained from pilot assessments implemented in different operational, environmental and socio-economic conditions, has contributed to the development of a systematic approach to manage reliance and potential impacts of e&p global operations on BES.

This distinctive approach to BES management includes (i) global mapping and assessment of all sites against areas of high biodiversity value, (ii) implementation of site-specific BES assessments and action plans in operating sites ranked as high priority with respect to biodiversity, and (iii) incorporation of BES evaluations into Environmental Social and Health Impact Assessments (ESHIAs) in new operating sites.

As an example of site-specific BES assessments and action plan, this paper illustrates the experience from an in-field pilot project in Congo, with a particular focus on the importance of combining landscape-scale and site-scale surveys and assessments.
Using Incident Data as Leading Indicators in the Assessment of Major Incident Risk within JV Operations.
Authors: Smith Don , Linzi Paolo
Published: June 2014

E&P organisations continue to strive towards improving HSE performance within their own operated activities. However, an area where there has been relatively little focus is on how Joint Venture (JV) Operators manage major incident risk within JV operations. Within these types of activities, the JV Operator is relied on to deliver the appropriate HSE performance, with the other JV partners adopting a predominately reactive approach to HSE issues that occur during the operation.

Against the background of a continued drive to improve HSE performance within all its activities (both operated and non-operated) and to understand and manage its exposure to major incidents within JV operations where it is not the operator, a methodology has been developed within eni UK to provide an indicator of the major incident potential within the non-operated joint ventures the organisation is engaged in within the UK sector.

The methodology is based on comparing and combining different measures of major incident risks. In particular two aspects are addressed: the estimation of major incident risk inherent in the JV operation and a measure relating to the manner in which the operator is managing the barriers required to prevent a major incident from occurring.

The paper presents an overview of the methodology then focuses on the use of incident, near miss and operational (event) data as a means of assessing the integrity of the barriers required to manage major incident risk. Examples of the type of information results from the use of the event data are presented.
Non-Technical Skills and Crew Resource Management
Authors: Flin Rhona , Wilkinson Jill
Published: June 2014

Major accident investigations in the energy sector have highlighted the protective role of non-technical skills. These are the cognitive and social skills that complement technical skills to achieve safe and efficient performance. They include situation awareness, decision making, leadership and teamwork: skills that are influenced by performance shaping factors, such as stress and fatigue. These skills are the focus of ongoing human factors research to provide an evidence base for training in aviation and other high reliaibility industries, in the form of Crew Resource Management courses. Our behavioural research from flightdecks and operating theatres has identified key non-technical skills for airline pilots, surgeons, anaesthetists and scrub nurses. These taxonomies have been developed into observational rating systems for workplace based competence assessment of non-technical skills which are now used in a number of countries. Drawing from this research, as well as from two recently completed projects on Crew Resource Management, sponsored by the Energy Institute and OGP (Oil and Gas Producers), this paper will examine background research on non-technical skills for wells operations and optimal methods for introducing a non-technical skills approach to the energy sector. It will examine methods of indentifying key non-technical skills for target occupations and will consider emerging issues relating to Crew Resource Management training design and implementation. Professional and scientific implications of non-technical skills assessment procedures will also be discussed.
Tele-Cardiology in Remote O&G Premises
Authors: Panait Dragos , Frano Mika
Published: June 2014

The availability of new technologies and communication systems allowed the Corporate’s Medical Department to start the implementation of a new approach in health protection and prevention, emergency management as well as in monitoring of employees with certain health risks.

Reports analysing the repatriation cases starting with year 2006 highlighted a high percentage of pathologies related to cardiovascular system representing the main not-work related cause for early work shift interruption. In fact this group of pathologies held the first place in the top three main causes of repatriation for 5 years in a row until 2011 when finally it has been dethroned by digestive diseases pathologies group.

After implementation of Tele-cardiology, it was expected that the number of repatriations due these illness (or at least those preventable) to gradually decrease in the following years.

Persons who are considered fit for work but have a certain chronic pathology, increased level of CV risk (diabetics, Hypertensive, impaired fats metabolism, cardiopathy, obesity, post AMI, by pass surgery, etc.) and whose health should be closely monitored, are included in monitoring programs and benefit of a consultation of the world-class specialist.

Extended health monitoring of the employees during the working period, make them feel and effectively be safer from the Health point of view. Preventing the emergencies and assuring a more cost effective health management are secondary objectives none the less as important as the main goal of such prevention oriented program.
BOP Reliability monitored Real Time
Authors: Huse Jan Reier , Alme Inge A.
Published: June 2014

The BOP is a complex construction with multiple parts and systems integrated. Any single failure will affect the overall functionality of the BOP. A key question will always be whether a particular failure has such an adverse effect on the overall functionality that the BOP needs to be pulled for repair and hence drilling halted. The presentation will outline how a BOP is broken down into a detailed fault tree. The fault tree is modeled in the software tool RiskSpectrum® originally developed for assessing process safety of nuclear power plants. Once a failure of any part in the BOP assembly is detected, the information is fed into the model, and the effect on the overall availability of the BOP is evaluated through a predefined methodology. The results are displayed to the crew onboard through any easy to understand mimic. The operating crew onboard an offshore drilling unit can then continuously monitor the availability of the BOP and make decision on their further actions based on real time facts on BOP status.

The BOP model has been developed under a contract with and funding from a major drilling operator and Lloyd’s Register, with BOP manufacturers being directly involved. US Authorities has been kept informed on the development. A joint industry panel with representative from Mobile Drilling Unit Owners, BOP manufacturers and Operating Companies has been overseeing the work.

The model has been launched and training of the operators has been carried out. Results from the implementation will be available at the presentation at the conference.
Developing Operational Procedures for Safe and Efficient Application of New Process Control Functionality on the Drilling Rig
Authors: Iversen F. P , Daireaux B.. , Leulseged A.. , Mihai R. G. , Gressgaard L. J. , Bergerud R.. , Bruun B. T. , Balov M. K.
Published: June 2014

Introducing new control functionality on the drilling rig has an effect on handling of machinery and controls and on the overlying work process both on the rig and for off-site support. New operational procedures taking these factors into account are therefore required to ensure safe and efficient application of such new technology.

This paper presents a new method for developing operational procedures for the driller when applying a system for automatic safeguarding and optimization of pump and pipe control in drilling operations. This method has been developed and subsequently applied through a lengthy study. A laboratory test environment has been used for this purpose, containing an advanced drilling simulator with the safeguarding and optimization functionality integrated.

The method applied consists of three phases, all performed in the laboratory test environment. Initially, the measurable effect of use of the system on the driller’s performance was evaluated in detail, using a set of test cases and a series of test-personnel from a drilling contractor. Subsequently the ability to drill a well section with incorporated incidents and exceptions was studied. Finally, operational procedures were developed in cooperation with the test-personnel, again using the test environment for testing and checking of procedures.

In this development process the focus has been on varying system modes and on handling of system and drilling process exceptions, while taking into account the effect of human factors and the wider organizational context of work conduct.

The authors believe that the method described is a suitable way to develop procedures for application of new control functionality on the drilling rig, and would recommend that such studies should be performed for new technologies to be applied in control of drilling operations.
Mitigating Infectious Diseases in Company Workplaces through Business Partnerships
Authors: Diara Malick , Johnson Clarion , Dockins Richard , Buford Deena , Edet Affiong Ben , Ngunjiri Susan , Brown Amanda
Published: June 2014

This communication describes how the company established a corporate steering committee and programs built on operations systems to effectively protect its large globally mobile international workforces from vector borne diseases, outbreaks, and other communicable diseases.

Application:

Infectious diseases have potential for serious health consequences, operation disruption, loss of productivity, and impact on a company’s license to operate and reputation. Mitigation of such threats in the oil and gas sector requires corporate commitment, intricate partnership between Operations, Security, Safety, Health and Environmental (SSHE) organizations with consistent use of effective mitigation measures built on company processes.

Observations:

Global implementation of the Company malaria control program decreased reported cases from 230 in 2002 to less than 15 since 2005. Chemoprophylaxis compliance testing developed with corporate funds was instrumental in such success. Following the deployment of Infectious Disease Outbreak Management in 2010, average number of affected workers during outbreaks decreased from 23 in 2010 to 12, in 2012. The Steering Committee for Infectious Disease Control assembles Company executives, SSHE managers and Medical and Occupational Health (MOH) department representatives. The committee and attached unit periodically review program needs and performances while providing guidance and resources for program improvements. MOH and SSHE organizations work in partnership with Operations and providers for tool development and updates, program implementation, effectiveness reviews and reporting. The Company operations integrity management systems include also effectiveness reviews of infectious disease control program in operations sites.

Significance:

The visible engagement of Company Executives in workplace infectious disease control programs is critical. Embedding disease control program procedures in company mechanisms, and building internal partnerships between Operations, providers, MOH and SSHE organizations are essential for the effective protection of oil and gas workers exposed to emerging and re-emerging infectious diseases around the globe. It also prevents spread of outbreaks from the operation sites to surrounding communities.