bluuebunny/crossref_metadata_2025_split huggingface dataset:
Sustainability Reporting And The Oil And Gas Industry - Challenges And Emerging Trends
Authors: Janus Bertrand , Murphy Helen 
Published: June 2014

ABSTRACT
Sustainability reporting is both a responsible and expected method for companies to communicate publicly on their environmental and social performance. The oil and gas industry has achieved many notable successes in the field of sustainability but challenges remain and it is becoming increasingly important for individual companies to tell their own stories in a clear, transparent, and straightforward manner.
For oil and gas companies, reporting can provide a robust platform for describing how strategic issues are being addressed through long-term plans and current initiatives. Stakeholders can find details of a company’s high level vision and strategy for dealing with sustainability-related impacts, implementing action plans and assessing outcomes.
Sustainability reporting within the oil and gas industry has evolved significantly over the past ten years with increasing numbers of companies producing reports, and these reports then being presented in ever more dynamic ways. There is an increasing focus on reporting as a critical engagement process with company stakeholders as well as employees, and organisations are now reporting on many more indicators than in the past, particularly regarding social and economic issues.
As a result, the sustainability reporting landscape is continuously evolving as companies find new ways to report on the ways in which they conduct their operations. This paper will examine best practices in the oil and gas industry’s reporting on sustainability and will discuss the following aspects in more detail:
- Industry reporting frameworks - Reporting challenges - Emerging trends in reporting
The Effect of Deluge Spray Systems on Large Scale Fires
Authors: Høiset Stian , Glittum Eli 
Published: June 2014

Abstract
A series of 56 large scale fire epxeriments in the range of 40 to 120 MW has been carried out in a generic offshore module. The effect of deluge fire water application has been measured for different set-ups. Both deluge nozzle type and water application rate have been varied in the experiments.
The main findings from the experiments are:
Deluge water application has better effect on liquid spray fires than on gas jet fires. A deluge water application rate of 10 (l/min)/m2 will have negligible or little effect on the highest gas temperature in the fire. A deluge water application rate of 20 (l/min)/m2 has a documented more favourable effect than an application rate of 10 (l/min)/m2. For gas jet fires, the flame hotspot temperature will persist, independent of deluge configuration. The choice of MV vs HV deluge nozzles is dependent on fire scenario. MV nozzles have their strength in reducing heat fluxes and iso-fluxes volumes, thereby reducing the amount of equipment and structure exposed to high radiation load. HV nozzles have their strength in ability to equipment cooling and lower vulnerability to wind.
25 Years of Operating Germany's Largest Oilfield Mittelplate: Applying the Experience to Exploratory Drilling in a National Park which is an UNESCO World Natural Heritage Site
Authors: Oppermann H.. , Zettlitzer M.. 
Published: June 2014

Abstract
Germany’s largest oilfield Mittelplate is located in the tidal flats of the Wadden Sea off the North Sea coast. In 1985 this unique area was designated as a National Park and was awarded the status of an UNESCO World Heritage Site in 2009.
To meet the conditions of this ecologically sensitive tidal region an artificial drilling and production island - Mittelplate A was designed and installed about 7 km off the coast. Since the start of production in 1987 innovative and unusual technological solutions were a prerequisite for achieving safe, environmentally compatible development of the Mittelplate oil reservoir. 25 years of incident-free operations show that the sensitive ecosystem is not impacted by any work being carried out. Sophisticated monitoring and control systems and the deployment of experienced, responsible specialists ensure safe and environmentally friendly drilling and production operations with highest quality.
Of key importance are open discussions with the competent authorities, the National Parks Board, nature conservation and environmental associations, the municipalities and other stakeholders, e.g. NGOs.
Additional oil reserve potential has been identified in the vicinity and south of Mittelplate oilfield which needs to be explored by drilling four wells in the National Park environment. A Wadden Sea Exploration Project has been set up and the experience of the Mittelplate operation will be utilized during all phases of this campaign, i.e. engineering, approval, construction and operations.
The exploratory drilling will be performed with a special designed barge based drilling rig setup. As conventional production tests are not allowed an extended logging and sampling program will be executed in case of discoveries. Afterwards the wells will be plugged and abandoned and the four drilling sites will be completely restored. In case of commercial discovery the reserves will be developed either from the existing Mittelplate A facilities or from onshore with Extended Reach Drilling up to 15 km TD.
Norwegian Oil and Gas Industry Project to Reduce Hydrocarbon Leaks
Authors: Vinnem Jan Erik , Røed Willy 
Published: June 2014

Summary
The prevention of hydrocarbon (HC) leaks is of great importance because they are the most critical precursor events that may lead to major accidents, such as in the case of Piper Alpha. The number of HC leaks on offshore production installations on the Norwegian continental shelf (NCS) peaked just after the year 2000, with more than 40 leaks per year of an initial rate greater than 0.1 kg/s. The Norwegian Oil and Gas Association (Norwegian Oil and Gas) conducted a reduction project from 2003 to 2008, which resulted in only 10 HC leaks greater than 0.1 kg/s in 2007. The number of leaks increased in the years after 2007, and there were 15, on average, in the period 2008–2010, without any significant increase in the number of installations. Norwegian Oil and Gas started a new project early in 2011 to reduce the number of HC leaks yet further. The initiative will be completed at the end of 2013, but has already started to show promising results. A study undertaken as part of the project concluded that more than 50% of the leaks are associated with the failure of operational barriers during human intervention into the process systems. Human and organizational factors predominate with respect to circumstances and root causes. This paper presents the HC-leak-reduction project, the rationale behind it, and its main activities, which aim to reflect the operational challenges. The activities tie in closely with the results of the analysis of the leaks during the period 2008 through 2011. The single operational barrier that has failed most commonly is the verification of critical activities. The paper also discusses the risk-reduction principles in a barrier context, with an emphasis on operational barriers, as well as some of the challenges faced in the project.
Leading from Within: Awakening Personal Commitment to Safety
Authors: Blair Seb 
Published: June 2014

Abstract
Leaders lead with everything they do and say, whether they intend to or not. In our work we’ve seen that reality put many leaders far outside their comfort zones. Safety leadership isn’t just initiatives and numbers. It’s personal. As many leaders have learned, people remember most what you do in situations involving people and principles—for example, whether (and how) you approached employees working at-risk or challenged decisions that increased exposure.
Developing the strength to do the right thing in these moments (and in all the other ones) comes from having a clear and unshakable emotional commitment to safety. In other words, to lead safety well, you first need to care about it. The good news is the value for safety is something we all inherently have. It may be dormant or poorly defined, but it is something we as leaders can awaken and use to drive our decisions, actions, and communications. When we cultivate a deep emotional commitment to safety, we provide ourselves the tools to navigate the hard moments effectively. Most important, we engage the hearts and minds of others to awaken their own commitment to safety.
Beyond PSM: Integrating Culture and Leadership into Process Incident Prevention
Authors: Blair Seb 
Published: June 2014

Abstract
Prominent incidents such as Oxy’s Piper Alpha explosion, the Esso Longford gas explosion, and the BP Deepwater Horizon spill have given rise to new rules and practices in the implementation of process safety management. Despite this attention, major incidents continue to occur. Research has shown that alongside the proximate causes of each incident, there also existed an underlying fabric of systems, mechanisms, and culture that allowed risk to persist and processes to be ignored. The conclusion is that traditional approaches to process safety management are not sufficient for addressing the precursors that lead up to catastrophic events.
Leaders in process safety management have recognized that the systems designed to control and mitigate major events are only as effective as the culture in which they operate. Leaders create culture through what they do and what they do not do, culture shapes behavior, and behavior is how systems are implemented.
To advance beyond the level of safety achieved through process safety management systems alone, organizations should adopt a Comprehensive Process Incident Prevention approach that builds on the foundation of process safety management to create a safety process that integrates culture with leadership characteristics critical to catastrophic event prevention. This approach includes four major components: Anticipation, Inquiry, Execution, and Resilience. Both individually and collectively, these four components build a strong safety culture that supports effective technical and management safety systems that are designed to prevent catastrophic events.
Examination of Static and Dynamic Filtration on Core Plug Samples on High Temperature
Authors: Federer-Kovács Gabriella , Mátrai Andrea 
Published: June 2014

Abstract
Developing drilling mud technology follows the industrial needs but in the interest of reducing formation damage the object is choosing the most suitable mud. It is even more important question when the pressure and temperature in a well is high. This paper tries to make this choice easier by measuring static and dynamic filtration of drilling mud on changing temperature.
Before designing a HPHT well there are two important cases which must be considered, the margin between the fracture gradient and the pore pressure is small what is critical in the design of the well and HPHT wells usually have high ECD (Equivalent Circulating Density) that leads to lost circulation problems that becomes difficult to control. The choice of accurate mud density is critical due to the narrow margin between the pore pressure and the fracture gradient. The applied mud has to stay stable under extreme temperatures and pressures and has to have optimized rheology to minimize ECD.
In our presentation we will show the results and comparison of the experiments that were conducted using a dynamic HPHT filter press with core sample plugs as filters both static and dynamic conditions to determine the filtrate and thickness and composition of the filter cake. The quantity and quality of spurt loss and fluid loss was compared on different temperatures and core samples. Filtration rate is one of the most complex mud properties because it may be influenced by almost any change in other properties-rheology, composition and particle size distribution-and in this way its effect on formation damage. At elevated temperatures these effects are more significant.
Fracturing a Non-Conventional Oil Reservoir Offshore Congo - Case History
Authors: Garcia Euro , Orski K , Marpaung F , Gonzalez-Dunia J , Bertin J 
Published: June 2014

Abstract
The oilfield Tchendo, located 18 miles off the coast of the Republic of Congo, has been operated since 1991 by Total E&P Congo in depths of approximately 100 meters of water.
The shallowest of the three reservoirs, the Sénonien reservoir (400 m TVD SS), involves an intercalation of carbonate layers with thicker (5 to 15 meters) but poorer quality siltstones.
Various attempts to enhance productivity on existing wells were unsuccessfully carried out since initial production, including selective or extensive perforation, acid treatments on the carbonate layers, and, in recent years, hydrajetting fracture stimulation on three wells.
Although the field is non-conventional, so far, it has been developed conventionally. A large amount of the original oil in place still remains in the reservoir. To make the redevelopment project viable, a step change in stimulation techniques is to be undertaken.
Two workovers were performed at the end of 2012 as a "proof-of-concept". Innovative fracturing technologies, including hydrajetting, were combined to deliver a non-sleeve scenario for horizontal well multi-stage fracturing. The workovers resulted in the largest fracturing treatment executed by Total on an offshore well.
This paper reports on the lessons learned in the process of fracturing this non-conventional reservoirs that will be capitalized for the future redevelopment of the project.
Flow Units: From Conventional to Tight-Gas to Shale-Gas to Tight-Oil to Shale-Oil Reservoirs
Authors: Aguilera Roberto 
Published: June 2014

Summary
Core data from various North American basins with the support of limited amounts of data from other basins around the world have shown in the past that process speed or delivery speed (the ratio of permeability to porosity) provides a continuum between conventional, tight-, and shale-gas reservoirs (Aguilera 2010a). This work shows that the previous observation can be extended to tight-oil and shale-oil reservoirs. The link between the various hydrocarbon fluids is provided by the word “petroleum” in the “total petroleum system (TPS),” which encompasses liquid and gas hydrocarbons found in conventional, tight, and shale reservoirs.
Results of the present study lead to distinctive flow units for each type of reservoir that can be linked empirically to gas and oil rates and, under favorable conditions, to production decline. To make the work tractable, the bulk of the data used in this paper has been extracted from published geologic and petroleum-engineering literature.
The paper introduces an unrestricted/transient/interlinear transition flow period in a triple-porosity model for evaluating the rate performance of multistage-hydraulically-fractured (MSHF) tight-oil reservoirs. Under ideal conditions, this flow period is recognized by a straight line with a slope of –1.0 on log-log coordinates. However, the slope can change (e.g., to –0.75), depending on reservoir characteristics, as shown with production data from the Cardium and Shaunavon formations in Canada. This interlinear flow period has not been reported previously in the literature because the standard assumption for MSHF reservoirs has been that of a pseudosteady-state transition between the linear flow periods.
It is concluded that there is a significant practical potential in the use of process speed as part of the flow-unit characterization of unconventional petroleum reservoirs. There is also potential for the evaluation of production-decline rates by the use of the triple-porosity model presented in this study.
Design Parameters and Technique Evaluation of Combustion Processes from Tube Testing
Authors: Oliveros L. R. , Yatte F. C. , Bottia H. , Muñoz S. F. 
Published: June 2014

Abstract
In situ combustion (ISC) is one of the improve recovery methods with a high potential to increase the recovery of heavy crude oil. Although we mentioned this major advantage, this process has not being used in Colombia yet. This fact due mainly to the complexity of the involved phenomenon, therefore a field project must be design after extended laboratory investigation.
Experimental tests in combustion tubes made through the main conditions in the oilfield have being the process' evaluation tool with the highest acceptance. These tests show the speed and stability of the combustion front and the obtained results from the production's analysis of fluids, mainly the ones of the exhaust gases. It is possible to calculate the basic combustion parameters by using: combustible consumption, required air, air- combustible relation, hydrogen- carbon atomic, and oxygen use. The parameters mentioned before let, trough different scaling analytic methods to evaluate the technical and economic viability of the process in the field.
In this work was developed a computational tool that allow calculating the design parameters through different scaling analytic methods Nelson & McNeil, Gates & Ramey y Moore et al). Comparing the results got from the different described methods, when scaling two tests in a combustion tube, they show similar numbers. Taking into account that Nelson and McNeil's method is the most useful one due to the oilfield characteristic, it was made a sensitivity of operational parameters and the result permitted to study the relation between the oilfield operational variables
Removal of Manganese Tetraoxide Filter Cake Using a Combination of HCl and Organic Acid
Authors: Al Moajil Abdullah Mohammed , Nasr-El-Din Hisham A. 
Published: June 2014

Summary
The removal of filter cake generated by drilling fluids weighted with manganese tetraoxide (Mn3O4) particles may require strong acids [e.g., hydrochloric acid (HCl)]. Organic acids are not efficient with high-density drilling fluids (&gt; 100 lbm/ft3) that contain large amounts of weighting materials (e.g., Mn3O4). A single stage of HCl treatment in a high-temperature and corrosive environment cannot be used. In certain cases, a two-stage treatment is recommended first to degrade polymers, and then to dissolve the solid particles in the filter cake. The reaction of acids with solid particles in the drilling fluids was investigated as a function of time at reaction temperatures up to 250°F. The solubility of the filter cake was examined using a high-pressure/high-temperature (HP/HT) filter press. Gas chromatography was used to analyze produced gases. Atomic absorption was used to measure the ion concentrations in spent acids, and X-ray diffraction was used to analyze solids. A safe, efficient, and economic technique that involves mixing HCl and an organic acid was developed to dissolve the filter cake in a one-stage treatment. The results showed higher removal efficiency (&gt; 85%). The solubility of Mn3O4-based filter cake using 10 wt% HCl at 250°F was 80 wt%, but the reaction released chlorine gas, which is toxic and corrosive. HCl concentrations less than 5 wt%, the release of chlorine gas was not significant, but the solubility of the filter cake was low. Lactic acid alone did not dissolve the filter cake. However, a combination of 4 wt% lactic acid and 1 wt% HCl dissolved Mn3O4 particles completely at 190°F. At a temperature of 250°F, nearly 85 wt% of the filter cake was dissolved. This technique uses lower concentrations of HCl/organic acid, which would reduce the cost of the acids required for the treatment. Using HCl alone is an inexpensive approach but HCl cannot be used at concentrations above 5 wt% with Mn3O4-based filter cake. In addition, a third method was examined to remove the filter cake using a combination of organic acid and enzyme.
Large Scale Jet Pump Performance Optimization in a Viscous Oil Field
Authors: Singh Manjit K. , Prasad Dhruva , Singh Aditya K. , Jha Mihir , Tandon Rohit 
Published: June 2014

Abstract
This paper discusses the performance monitoring and optimization of large scale jet pumping in Mangala field, one of the biggest onshore fields in India. Mangala field is characterized by multi-Darcy sandstones, containing waxy and viscous crude oil. Currently, the field is producing at plateau of 150,000 BOPD.
The base development plan for the field included hot water flooding; this also makes water heated up to 80 °C available at the well pads as power fluid for jet pumping. Jet pump was selected as the preferred artificial lift method in deviated wells, as it addresses all flow assurance issues arising due to high wax appearance temperature of Mangala crude.
Jet pumps provide the required drawdown for sustained liquid production both at low and high water cut. With significant number of wells operating on jet pump, it has become crucial to monitor the performance and optimize for maximum efficiency application by varying operating parameters, changing the nozzle throat combinations and making other adjustments. Currently, Cairn is monitoring the real time jet pump operating parameters on a daily basis by virtue of DOF (Digital Oil Field). DOF has not only eased the tedious task of jet pump monitoring in bulk but also has reduced the response time to any failures/damage in the pump. Liquid handling capacity of the processing plant has become crucial with increasing field water cut and more jet pump installations. Jet pump performance optimization for maximum efficiency has now started to play an important role in not only reducing the burden of the processing facility but also in improving the production profile of the wells.
This paper will discuss the use of a methodology based on an in-house developed algorithm for monitoring the efficiency of the pumps, with supporting field examples. This paper will also make an attempt to analyze the effect of different operating conditions on the pump performance curves published in the literature.
Design and Execution of a Polymer Injection Pilot in Argentina
Authors: Hryc A. , Hochenfellner F. , Paponi H. , Puliti R. , Gerlero T. 
Published: June 2014

Abstract
A polymer injection pilot for El Corcobo Norte field started in January 2012 in Neuquén Basin, Argentina.
The pilot aims to improve volumetric efficiency for Lower Centenario unconsolidated formation.
El Corcobo Norte field produces medium-heavy oil and has been under waterflood since the very beginning of the field's production in early 2006. A fresh water source is used to make up oil volume and maintain the injection-production balanced.
The fact that Lower Centenario formation is strongly water-wet has helped to reach a successful waterflooding process. Field development plan was carried out with an inverted 7-spot pattern configuration of approximately 60 acres. Production strategy involves strong sand production during well completion, followed by a low constant sand cut during producer's life. Sand production, among other factors, has shown to be responsible for water channeling issues and even wormhole generation, that lead to a decreased efficiency and compromise reserves. Polymer laboratory experiments were conducted to design and calibrate numerical simulation, both lab and pilot scale.
This work will present the challenges faced for the design and implementation of a polymer pilot when dealing with medium-heavy oil, sand production and channeling in order to increase recovery factor. We will summarize as well the project's results up to date and lessons learnt in the field experience.