bluuebunny/crossref_metadata_2025_split huggingface dataset:
Innovative Hybrid Rotary Steerable System Allowed Drilling a 6 in. Horizontal Hole Through a Carbonate Reservoir With a Record Dog Leg Severity of 13°/30m
Authors: De Grandis G. , Maliardi A. , Gioia V. , Paoli F. 
Published: December 2014

Abstract
This paper describes the successful field test of an innovative hybrid Rotary Steerable System (RSS) developed for high Dog Leg Severity (DLS) applications. This novel technology has been applied for the first time in Continental Europe to drill a sidetrack well in a sensitive area where the application of new technologies is strictly related to the commitment to minimize the environmental impact of well operations activities.
The sidetrack was drilled to optimize the oil recovery from a carbonate reservoir. A solution was needed to drill the 6 in. sidetrack horizontal well starting from a 7 in. casing window, which must be opened just below the top of the reservoir due to operational constrains.
The challenge was to reach the targets, identified by the reservoir geologists to increase the reservoir exposure and maximize the oil production, while ensuring an optimum borehole quality. This required an optimal trajectory design and an accurate directional drilling control to land the well in the shallower part of the reservoir, far away from the Oil-Water Contact (OWC). A 3D well plan was engineered, with DLS up to 10°/30m. In the past, similar wells were drilled with a Positive Displacement Motor (PDM), which often produced poor hole quality. The novel hybrid RSS used to drill the sidetrack well has internal pads that push against an articulated sleeve pivoted on a universal joint to point the bit in the desired direction, enabling high build-up rates and a smooth wellbore.
The field test demonstrated the reliability of the system which successfully drilled the 6 in. curve section with a maximum DLS of 13°/30m, yet with an optimum wellbore quality. The performance was further enhanced by using a Polycrystalline Diamond Compact (PDC) bit specifically designed for compatibility with such innovative hybrid RSS.
This paper describes the field test and the well engineering process that led to the successful application.
Improving Safety Risk Tools for Accidental Fluid Releases with High H2S Concentrations
Authors: Nilsen Sandra , Høiset Stian , Salaün Nicolas 
Published: December 2014

Abstract
Statoil has substantial experience from safe design and management of safety risks associated with hydrocarbons and CO2 handling. Modelling of accidental releases is an integrated part of the safety risk management process - to verify safe design, layout and tolerable risk.
Modelling tools for hydrocarbon releases are well validated and verified against experimental data. Safety analyses for projects where the content of H2S in the process stream is considerable have revealed that there is limited experimental data addressing releases of H2S rich hydrocarbons. It was observed that the computer tools can give substantially different results with respect to dispersion distances for the same accident scenario. The variations seem to be larger when the stagnant conditions are liquid or 2-phase.
The scarcity of experimental data for H2S rich fluids and variations in results in calculations give reasons to implement results from risk analysis with caution.
This paper will present the results from a literature study that has been carried out in order to start closing the knowledge gaps along with consequence calculations for relevant release scenarios. The object of the literature study was to identify relevant models, their strengths, and weaknesses together with a survey of relevant experimental data. The results indicate that there exist so called simple models and algorithms that can take into account H2S specific properties. However, there are very limited, if any, experimental data to verify the accuracy of the models. It also became clear that very few CFD codes can model the complex thermodynamic processes during expansion of H2S rich hydrocarbons. The same situation is applicable for jet dispersion where the fluid is mixed with ambient atmosphere.
As a result of this work it is recommended to establish more relevant experimental data.
Technical Integrity Management in Statoil
Authors: Refsdal Ingbjorn , Urdahl Olav 
Published: December 2014

Abstract
In today's business environment, technical integrity management is fundamental in order to meet expectations from stakeholders, both internally and externally. The term technical integrity is in Statoil defined as "A system or a facility's ability to function as intended and in accordance with regulations (regulatory requirements) and internal provisions".
Technical integrity is vital for safe and effective operation of our facilities. Managing risk in Statoil is everyone's responsibility, directly or indirectly.
This paper outlines Statoil's risk based approach to an integrated, cross-disciplinary system for management of technical integrity. The work was initiated in 2010 with the aim to develop and implement a new technical integrity management system for measuring and follow-up of the technical condition of various safety barriers. The systems to be included in this were well, production and transportation systems, and load bearing structures. This initiative was named TIMP – Technical Integrity Management Programme.
TIMP consists of:
A comprehensive competence programme A standardised work process to follow up and visualise technical integrity A methodology to assess the technical condition at equipment-, system and facility level An IT tool to visualise the technical integrity and assist daily work processes.
Details of each element of TIMP are further outlined in the paper, and the challenges and learning from the development and implementation of TIMP on various assets are summarized.
Immiscible Nitrogen Injection: A Challenging Experience on Depleted Naturally Fracturated Reservoir
Authors: Vazquez A. J. , Guerrero R. , Ancona M. A. , Hernandez R. , Colin G. , Rodney C. 
Published: December 2014

Abstract
Pressure maintenance through immiscible nitrogen injection has proved to be one of the best methods as a secondary oil recovery on depleted and naturally fractured light-oil reservoirs (NFR).
The 190 MMscfd of immiscible nitrogen injection project that is currently developed in the Antonio J. Bermudez Complex, a giant NFR in Southern Mexico, is the second large pressure maintenance project in Mexico, after the world famous Cantarell project. A lot of challenges dealing with injection well locations, injection rate control, fracture system effect on nitrogen breakthrough and impact on hydrocarbon gas contamination, have been managed the last six years of project performance.
A comprehensive description of the pressure data acquisition program, the importance of the real time and planned chromatography to monitor the reservoir performance, the methodology to determine the net oil recovery contribution and the methods to define the vertical and horizontal efficiencies are described in this paper focused on learning lessons and best practices.
The experience gained over the six years of the nitrogen injection project show that this process is beneficial to extend the life of a depleted light oil reservoir as remedial solutions for mature oil fields revitalization.
Fibre Optic Four Mode Leak Detection for Gas, Liquids and Multiphase Products
Authors: Worsley Jerry , Minto Chris , Hill David , Godfrey Alastair , Ashdown James 
Published: December 2014

Abstract
Many variants of pipeline line leak detection systems are in operation today on liquid or gas pipelines. These often rely upon a single leak detection methodology. This could include; CPM, Mass Balance, Acoustic, Flow or Temperature Monitoring. Latest developments in fibre optic technology now mean that a number of these methods can be combined in a single system. Fibre Optic Distributed Acoustic Sensing (DAS) is able to use the following measurands to detect within leaks seconds with a location accuracy of 10 meters.
DAS detects the following signatures of a leak; Acoustic Anomaly; Temperature Gradient, External Ground changes and Negative Pressure Pulse. By fusing these signatures together DAS is able to provide a sensitive yet robust and reliable leak detection solution. Added benefits of the system are also the traditional security aspects that help prevent as opposed to detect pipeline damage as well as Inline Inspection Gauge Tracking through the same hardware set.
This paper examines the methodologies used to detect leaks in all phases of products. Discusses the industry led tests conducted so far and provides real life evidence of leaks detected in the field.
Using Multiple Realizations from an Integrated Uncertainty Analysis to Make More Robust Decisions in Field Development
Authors: Hegstad B. K. , Sætrom J. 
Published: December 2014

Abstract
This paper describes the workflow for an uncertainty study for a field development case offshore Norway. It is a workflow where uncertainties in seismic time interpretation, depth conversion, contacts, fault scenarios, alternative conceptual models, facies models, relative permeability, schedule etc. are included in an automated way to generate multiple realizations (hundreds) of the geomodel and reservoir model. Hence all uncertainties in the geomodel are also included in the reservoir model explicitly, and are captured by the ensemble of realizations. Since structure, contacts and facies distribution are different from realization to realization the workflow ensures that the planned well trajectories are automatically adjusted accordingly.
Having such a workflow which can generate and manage multiple realizations makes it straight forward to get robust and realistic estimates of uncertainties in in-place volumes and produced volumes. It is also used for risk mitigation and decision support as e.g. to evaluated robustness of well placement, well number, top side capacities etc.
This automatic workflow made it easy to rerun the uncertainty study when new well-data arrived. It made it also easy to run sensitivities on any part of the reservoir modelling workflow to gain valuable insight. Furthermore, having such a workflow made it possible to do quick and simple soft conditioning on dynamic data (such as drill stem test data) or alternatively use the dynamic data as direct input to the geomodel.
Few real data from the field under study will be included. Those who are included are anonymized and scales on axes are masked.
The Role of 3D Rock Chips and Cutting Area Shapes in PDC Bit-Design Optimization
Authors: Chen Shilin , Grosz Greg , Anderle Seth , Arfele Rob , Xun Keshan 
Published: December 2014

Abstract
Almost all previous cutter force models assumed that cutting force was proportional to cutting area. Cutting-area-based single cutter force models have been extensively used in polycrystalline diamond compact (PDC) bit design optimization. This paper explains why cutting-area-based bit models failed to predict bit forces. A new cutter force model and a new bit model have been developed and are discussed in the paper. In the new cutter force model, cutting force is a function of the shape of the cutting area. Three types of cutting shapes are respectively modeled. In the new bit model, three-dimensional (3D) rock chips created in front of cutting face are modeled, meshed, and removed from the hole bottom by updating the hole bottom at each time step. To validate the new model, six different PDC bits were designed, manufactured, lab tested under controlled conditions, and field tested. Details from laboratory testing and field-test results are presented.
Successful Polymer Flooding of Low-Permeability, Oil-Wet, Carbonate Reservoir Cores
Authors: Bennetzen Martin Vad , Gilani Syed Furqan , Mogensen Kristian , Ghozali Muhammad , Bounoua Noureddine 
Published: December 2014

Abstract
The majority of polymer applications to date have targeted medium-to-high permeability sandstone reservoirs containing reservoir brine with moderate salinity and hardness. Polymer flooding for enhanced oil recovery has been field-tested in carbonates, but applications tailored towards oil-wet, low-permeability limestone rocks are uncommon.
This paper contains results from laboratory core flood tests performed on four strongly oil-wet limestone rocks from the Al Shaheen field, off-shore Qatar. The rock samples investigated had 25–30% porosity and 0.3–28 mD permeability; the reservoir brine had a salinity of about 120,000 ppm of which 10,000 ppm were divalent cations. The bulk fluid testing involved fluid compatibility tests, long-term stability tests, as well as rheology measurements. Three commercial polymers were screened, one of which successfully passed all the screening criteria. Core flood experiments were subsequently performed to determine relative permeability, adsorption, inaccessible pore volume, as well as permeability and mobility reduction. The crude oil had a viscosity of 8 cP at reservoir conditions, yielding a slightly unfavourable mobility ratio for the baseline water flood.
At concentrations of 500–1,000 ppm, the selected HPAM polymer gave rise to some mobility and permeability reduction, as expected, but it did not seriously plug any of the four low-permeability cores. The dynamic adsorption was very low, around 10–20 μg/g rock, the inaccessible pore volume was 15–20%, which is in line with industry experience, and the injectivity reduction was in agreement with ECLIPSE and UTCHEM simulations, which suggest that significant polymer degradation did not take place. The low adsorption is attributed to the strong oil-wetness of the rock. Since the polymer flows in the water phase, presence of a strong oil film likely prevents the polymer from adsorbing to the rock. The results from a subsequent water flood showed that inaccessible pore volume introduced by the polymer persists during the subsequent water flood; such a feature has yet to be incorporated in UTCHEM and ECLIPSE. In fact, the data revealed many features, which could not be adequately captured by numerical simulation tools.
The main conclusion from the laboratory work is that polymer systems with good viscosifying power can be tailored to recover oil from low-permeability carbonate rocks, pushing the permeability limit down to around 1 mD.
Major Key factors And Guidelines For Preparation Of Project Execution Strategy
Authors: Al Hammadi Nasser , Saud Shah 
Published: December 2014

Abstract
The fact that the majority of projects fail on at least one measure of success, and that billions of dollars in project waste is reported each year, suggests that there is a critical need for improving the way we manage these projects. The unrelenting truth is that the secret to more successful project management has been right in front of us the whole time - learning from the past and preparing for future. The best way to address the issue is thorough proper execution strategy.
The objective of this study is to identify major key factors & provide guidelines for preparation of successful project execution strategy predominantly in oil and gas industry where meeting the schedule is of utmost priority, especially in case of plant shutdown that is pre-planned for specific fixed period cycle to carry out preventive maintenance and unit replacement.
This study utilizes a Case Study approach from projects for data analysis statistics, Identifying major factors influencing Project Execution Strategy. Among various elements of Project Execution Strategy the Project Resources, Risk Management & Engineering Deliverable Review Strategy are focused providing in-depth analysis on 38 Major & 40 No's Technical project having capital investment of more than US$26 Billion.
Utilization of Resources Data Bank prepared based on various project and how it will help Project Management Team (PMT) to evaluate the resources requirement and subsequently the project duration based on available organization resources. The Preparation of Data Bank & their accessibility will help project management team to give quick analysis of project resources as well as project duration.
Further, Impact of Conducting Risk Analysis on project of complex nature is analyzed; a quantitative analysis on major 38 No's project provides the necessity of including the risk analysis as part of Project Execution Strategy. This research will provide a platform and source of guidelines for project manager's to produce efficient & SMART execution strategies for EPC Projects in particular for gulf region.
Stabilized and Increased Well Production Using Automatic Choke Control
Authors: Kittilsen P. , Fjalestad K. , Aasheim R. 
Published: December 2014

Abstract
Process fluctuations are often equivalent to lost production as the necessary margins to process constraints need to take into account the fluctuations. Better operation is achieved by reduced process fluctuations so that the average production may be closer to the constraints. This is achieved by automatic process control which also reduces operator load.
Wells which produce oil and free gas (coning) from the reservoir are sensitive to changes in operating conditions, and the gas and oil rates drift over time. This is natural because variations in coned free gas generate variations in wellhead pressure. This will in turn affect the production rate and the well drawdown. In manual operation, a common strategy is to operate with an excess of free gas or use artificial gas lift and manipulate the wellhead choke manually.
An automatic wellhead choke control solution is developed to reduce fluctuations and increase production rates. The two main elements in the automatic wellhead choke control are:
A robust measure of the controlled variable (i.e. the gas flow rate) A robust control strategy
Since the gas flow rate is not directly measured, a gas flow rate estimator was developed, with the premise that no hardware modification should be necessary:
The gas fraction in the well stream is determined from the pressure drop from the bottomhole to the wellhead The total multiphase well flow is calculated from either a venturi meter (if available) or the well head choke (based on choke pressure drop, travel, and characteristics)
The control strategy is to ensure fast corrections to keep the gas flow rate close to the specified set point, thus enabling a close-to-collapse operation of the established gas cone. The gas flow rate set point is specified to ensure that the well head pressure is sufficiently high, i.e. higher than the pressure downstream the choke.
The solution is implemented on several wells at various Statoil operated fields with gas coning into the wells. The solution gives stable well flow rates, and thus enables increased production. The operator workload related to well supervision has also been reduced. The method could also be applied to other that should remain constant, e.g. water cut, water flow, or GOR, as long as the quantity can be estimated (or measured), and will respond to well head choke manipulations.
ADCO Deploys the EFQM Excellence Model as a Management Framework for Sustaining Operational Excellence
Authors: Daoud Mohamed , Al Mansouri Bakheeta , Alaa Mohamed , Sulieman Amar Osman , Hegazy Haytham , Desi Hala , Al Bannay Nooran 
Published: December 2014

Abstract
Excellence became a necessity of our time topping the agenda of all professionals. As confirmed by our CEO in more than occasion; Excellence at ADCO is not a destination; it's a core value demonstrated as way of doing business.
The Excellence Journey kicked-off at ADCO since the inception as the company prides itself as a big advocate for QMS Systems in the Oil and Gas Industry. This was achieved by integrating all quality systems under the EFQM Excellence model. ADCO started in mid 90s implementing TQM principles led by our current CEO.
The recent implementation of the EFQM at ADCO came after the two updates of the model 2010 and 2013. Organizational assessment was conducted highlighting the areas for improvement (AFIs) which prioritized into a comprehensive action plan to ensure implementation across ADCO. The latest update is the adoption of the EFQM model within the oilfields piloted in the newly developed field (Qushawira).
The EFQM model is a practical, non-prescriptive management framework enables organizations integrates their existing and planned initiatives providing structure for the organization's management system. The model comprises of 3 components; the fundamental concepts, the 9 criteria and the RADAR logic.
Results and Conclusions:
The implementation of the EFQM model has materialized in enhancing the operational excellence culture. The management thinking and leadership style have moved to looking at the operational challenges as (AFIs) which made all leaders in a continuous search for new ways and methods of reaching performance excellence.
This was validated when ADCO participated in 2012 in the Sheikh Khalifa Excellence Award (SKEA) and achieved the Gold category in the Oil and Gas sector. Now, ADCO is preparing to apply for SKEA (2014). A lot have improved after winning the Gold Category in 2012 which qualifies ADCO to win higher category/ies in 2014.
Microseismicity Mechanism Investigation of Stochastic Microcracks Rock Model and Application in Hydraulic Fracturing
Authors: Li Wenjing , Zhao Wenyang 
Published: December 2014

Abstract
For the studies on hydraulic fracturing (HF), reservoir formations with natural fractures and their interaction with hydraulic fractures are more concerned. Stochastic Microcracks Rock Model is the microscopic numerical geo-model, which applies the Monte Carlo simulation of stochastic microcracks using Distinct Element Method (DEM). This model compiled in dynamic modeling codes presents more realistic behavior of the rock formations. For characterizing rock mass, the microseismic events are wildly regarded as the indicators of shear slip, and for unconventional reservoir, the induced microseismicity (MS) by HF can be applied in creation more flowing paths to increase very low permeability. Therefore, it is essential to investigate the MS source mechanisms in the rock mass, and with the effect of pre-existing fractures. In this paper, a modified analytical model of microseismicity is derived and verified with numerical simulations coupling Discrete Element Method by Particle Flow Code (PFC3D). The results show that there are the correlation between shearing microseismic event and interaction between hydraulic fractures and natural fractures; and fracture fluid could also contribute to the shear failure during stimulation. This combined numerical modeling provides a unique alternative method for understanding the controlling factors of MS gen-eration and its effect on stimulation. In addition, microseismic events possess the potential to characterize the fracture geometry qualitatively, to evaluate the fluid behavior in fractured formation, to predict fracture propagation, and ultimately to optimize stimulation design.