bluuebunny/crossref_metadata_2025_split huggingface dataset:
Microwave Heating: A Feasible Alternative for Drilled Cuttings Drying in Offshore Environments
Authors: Pereira M. S. , Ataíde C. H. , Naufel R. , Panisset C. M. , Sa C. H. , Martins A. L. 
Published: March 2013

Abstract
Drilled cuttings contaminated by Non Aqueous Fluids (NAF's) are a waste from oil well drilling activities. Over the past twenty years, studies have been conducted in order to assess the effects that these contaminated cuttings have on the environment. In Brazil, the environmental offshore discharge threshold for synthetic base is 6.9 % in mass. Microwave shows itself as a promising technology to remove the organic phase of these drill cuttings. This paper presents microwave heating technique as a new method for the treatment of contaminated drill cuttings. For this purpose, it was developed a batch microwave oven with capacity up to 6 kW. In experimental testing the mass input was 6 kg and the microwave oven was airtight. Microwave cuttings remediation was investigated for three different power inputs (3, 4 and 6 kW) at 0.50, 0.60 and 0.70 kWh/kg and for the specific energies ranging from 0.20 to 0.70 kWh/kg at 3 kW. The moisture content in a rehydration was also studied in cutting drying. The process can remediate the cuttings to below 2%, using the specific energy of 0.60 kWh/kg. The cutting drying by microwave heating is more efficient at low powers input. When cuttings that had already been dried were rehydrated and dried a second time it was observed that the smaller the amount of water content the better was the secondary removal of n-paraffin was.
Annular Pressure Build-up Analysis and Methodology with Examples from Multifrac Horizontal Wells and HPHT Reservoirs
Authors: Bellarby Jonathan , Kofoed Sara Sparre , Marketz Franz 
Published: March 2013

Abstract
Annulus pressure build-up (APB) remains an important design consideration for many wells, not just deepwater or subsea wells. This paper outlines a step-by-step methodology for analysing APB issues applicable to any type of well. Analyses of APB scenarios for a tight chalk oil reservoir and an HPHT gas-condensate reservoir in the Danish Sector of the North Sea are used to demonstrate the methodology.
APB is a potentially serious issue with HPHT wells created by annuli that heat up during production. The increased temperatures cause fluid expansion that can potentially over-stress the casing and tubing if not mitigated. Specific issues for HPHT wells are presented.
The significant increase in the use of multi-stage horizontal fracturing systems with open or cased hole packers and ball or intervention operated sliding sleeves creates a fluid contraction threat. Overpressure through annulus fluid contraction caused by cooling has been rarely analysed. A case is shown to disprove a common belief that the fluid external to the sleeves equalizes with the reservoir over the time frame of the stimulation operation which prevents over-pressurization. Failure cases are presented along with the design calculations required to assess the combination of tubing ballooning, fluid contraction / expansion and transient reservoir flow. It is demonstrated that with cases of toe-to-heel stimulation combined with low reservoir permeabilities, significant transient drops in pressure external to the sleeves can occur. This can lead to tubing, sleeve or packer failures.
Performance and Cost Benefits of Environmental Drilling Technologies: A Business Case for Environmental Solutions
Authors: Brantley Lydia , Kent Jennifer , Wagner Natalie 
Published: March 2013

Abstract
Environmental impact has become business critical as we have been unable to crack certain issues to the degree expected for our industry. It is the central challenge for the continued development of shale markets, as it has been offshore. In a customer survey completed in the first quarter of 2012, a diverse group of operators, drilling contractors, and service companies identified their top three challenges for shale development: pricing, inexperienced personnel, and—of paramount importance—environmental impact. The industry recognizes the need for reduced environmental impact, but what do we need to achieve it?
In the aforementioned survey, many operators and drilling contractors expressed looking to oilfield service and supply companies for continued innovation with the expectation that they continue to be to be forward-thinking and present ideas that provide value. The industry has two primary means for reducing environmental impact of its operations: processes (operator and contractor-driven) and equipment (service and supply-driven). This paper proposes that the two must work hand-in-hand. It explores the opportunity to take this further: identifying critical steps such as process design for reduced environmental impact with lower-impact technology and industrial engineering. The dual approach is needed to affect large-scale change.
This paper will examine the positive impact of the implementation of select environmental technology can have on oilfield economics from the perspective of an oilfield equipment, technology, and services provider. It aims to:
Demonstrate a case for environmental solutions Establish the importance of improved environmental performance for market access Identify areas in which operators evaluate environmental impact Discuss the technology opportunities available to operators Recognize and quantify the performance and cost benefits of aforementioned technologies.
A Summary Of Wired Drill Pipe Field Trials And Deployments In Bp
Authors: Edwards Stephen T. , Coley Chris J. , Whitley Nick A. , Keck Richard G. , Ramnath Vishwahnath , Foster Tommy , Coghill Keith , Honey Mark 
Published: March 2013

Abstract
The first use of wired pipe in BP was in early pre-commercial field trials in seven Oklahoma wells in 2004 to 2005 (Reeves et al, 2006). IntelliServ commercialized its networked drillstring or wired pipe with full connectivity to 3rd party downhole tools in early 2007.
BP field trialed the commercial version of wired pipe with a comprehensive suite of BHI's Loging While Drilling (LWD) tools, Measurment while drilling (MWD) and AutoTrak rotary steerable on two Wamsutter (Wyoming) wells in 2007. These wells achieved a number of "industry firsts" including the first use of IntelliServ along string pressure measurements and the first use of real-time high resolution wellbore imaging while drilling.
Since then, BP has deployed wired pipe commercially on more than 14 wells in 4 additional locations (Trinidad, North Sea, Colombia, and Deep Water Gulf of Mexico) representing a good cross section of drilling conditions and challenges (including wellbore stability, hole cleaning, BHA vibrations, formation pressure measurements in depleted zones, complex geology and challenging directional requirements).
This paper is a summary of the above experiences. It includes a discussion of the challenges and solutions in area such as hardware modifications (e.g. wiring top drives, reamers, jars) deployment, logistics, reliability, pipe handling and other operational modifications, surface connectivity and dataflow to shore. The bulk of this paper discusses wired pipe enabled applications while drilling.
Technological Innovation in Riser Tensioner Design Significantly Reduces Risk of Tensioner Overpull and Likelihood of Catastrophic Events
Authors: Watts Bob , Trent David 
Published: March 2013

Abstract
The "riser tensioner" is a primary component in the MODU's, mission critical, marine riser motion compensation system. Over the past decade, direct-acting tensioners have gained acceptance and are replacing wire line systems.
Because of the significantly longer hydraulic power piping runs associated with the popular direct-acting tensioner design and their less-than-efficient equipment piping arrangement, the influence of hydraulic friction (line loss) is significantly increased. This has a direct consequence of delayed system response to heave during normal operation. Delayed response will produce periods of over and underpull during each vessel heave cycle. Overpull has been directly linked to wellhead deformation and riser overload. Increasing riser string tension force range (hysteresis) increases riser string fatigue rate. A comparison analysis of two tensioner configurations, for an "average design" set of vessel heave parameters, shows that a solution exists to significantly diminish these risks.
The dynamic analysis performed compared the industry standard direct-acting tensioner assembly configuration and a modified, patented design that places the air-over-hydraulic accumulator bottles closer to the rods, thus significantly reducing liquid path length and consequential friction losses; mitigating overpull and its risk. Analysis indicates this to be the most effective corrective action for both existing installations and new builds.
Computational fluid dynamics (CFD) was used to analyze the fluid flow paths of a popular direct-acting tensioner configuration and modified direct-acting tensioner configuration. For the peak fluid flow rate associated with the heave, friction head was determined.
The popular configuration modeled can have a pressure variation of ±490 psi. This pressure variation will yield a per- tensioner tension variation (hysteresis) of 234,000 lbf. For a six-tensioner configuration, the heave-motion-induced marine riser string top tension variation can be 1,405,000 lbf. This result is significant. MODUs having this tensioner configuration should be reviewed and analyzed soonest. The modified configuration has a pressure variation of ±80.2 psi. This variation yields a per-tensioner tension variation (hysteresis) of 38,300 lbf and 230,000 lbf top-tension variation. Retrofitting the modified, direct-acting tensioner is an attractive, corrective action.
New Technology Enhances Rotary Steerable System performance and Provides Superior Borehole Quality and Reduces Vibration in Rotary Steerable Applications
Authors: Barton S. , Herrington D. , Gaines M. , Morrison R. , Stroud D. , Lines L. 
Published: March 2013

Abstract
Rotary steerable systems (RSS) have become a standard technology in today's drilling industry. With the advent of the RSS, have come new challenges associated with well bore quality, steerability, and vibration mitigation. The need for technology that supports and compliments RSS operations is the next logical step in providing optimized RSS drilling services.
While RSS technology allows drilling of extended reach horizontals and challenging well profiles, the systems have their limitations just as mud motors do. The demand for more complex wells has highlighted the need for technologies that can take the advanced capabilities of the rotary steerable system and push it to the next level of performance. A tool that maximizes the effectiveness of an RSS, reduces costs associated with RSS drilling, and improved borehole quality stands to add an entirely new level of value to rotary directional drilling.
A novel technology is now available that has been proven to improve lateral stability and increase bit life by as much as 50% while posting gains in ROP as high as 120% over offset data. Dramatically improved borehole quality has resulted in reduction in materials required for cementing by as much as 25% while reducing the time spent back reaming by 30% and in some cases, alleviating the need for back reaming altogether. Dramatically improved borehole quality in point-the-bit RSS applications. By providing a tighter gauged hole, the severity of downhole vibration and backward whirl were greatly reduced.
This paper provides supporting documentation that a technology proven to improve lateral stability while mitigating damaging downhole vibrations is assisting a major operator in maximizing the performance of their RSS operations and allowing operators a new level of performance and cost savings.
A New Measurement While Drilling System Designed Specifically For Drilling Unconventional Wells
Authors: Krase S. J. , Harvey P. R. , White M. W. , Earl T. G. 
Published: March 2013

Abstract
The recent drilling explosion targeting unconventional reservoirs has created extraordinary opportunities for growth in the oil industry and has also presented many challenges for the MWD industry.
Since the first commercial application of MWD in 1978, significant technological advances have been made. However, most of these advances have been focused on the development of technology for formation evaluation targeting the offshore environment and the higher operating costs associated with this environment.
Most of the existing MWD systems were developed for drilling directional wells through clastic or carbonate reservoirs and are not well suited for drilling unconventional drilling programs. The issues with existing MWD systems are associated with measurement accuracy, measurement type and BHA incompatibility. The requirements for an MWD system for drilling unconventional wells on land are; accurate well bore placement which includes directional drilling and geosteering, drilling efficiency and interfacing into automation systems such as automated top drives and MPD systems.
A new generation of MWD systems has been created specifically for the unconventional drilling environment. Starting with a blank sheet of paper enabled the development of a fit for purpose MWD system that meets the technical and financial requirements for drilling these unconventional reservoirs. The system is designed to fit the existing cost structure associated with drilling unconventional reservoirs on land. The system eliminates the need for dedicated MWD personnel at the wellsite thereby enabling remote directional drilling and also drilling automation. The measurements provided by the MWD system are focused on providing the information required for precise wellbore placement, drilling dynamics for drilling efficiency, annulus pressure to assist with MPD and formation measurements for geosteering. Perhaps most importantly the system is only 34 feet in length which makes it easy to place in the bottomhole assembly.
A Surveillance "Smart Flow" for Intelligent Digital Production Operations
Authors: Al-Jasmi A. , Goel H. K. , Nasr H. , Carvajal G. A. , Johnson D. W. , Cullick A. S. , Rodriguez J. A. , Moricca G. , Velasquez G. , Villamizar M. , Querales M. 
Published: March 2013

Abstract
Intelligent digital oilfield (iDOF) operations include the transfer, monitoring, visualization, analysis, and interpretation of real-time data. Enabling this process requires a significant investment to upgrade surface, subsurface, and well instrumentation and also the installation of a sophisticated infrastructure for data transmission and visualization. Once upgraded, the system has the capability to transfer massive quantities of data, converting it into real information at the right time.
The transformation of raw data into information is achieved through intelligent, automated work processes, referred to here as &#34;smart flows,&#34; which assist engineers in their daily well surveillance activities, helping make them more productive and improve decision making. A major oil and gas operator in the Middle East has invested in such an infrastructure and is developing a set of smart flows for key activities and work flows for its production operations, with the ultimate goal of improved asset performance.
This paper explains the development of the production surveillance smart flow, which provides engineers with automated artificial intelligence that analyzes data, provides guidance on well operations, and, when necessary, gives warning and alarms as conditions warrant them. The suite of artificial intelligence consists of advanced correlation statistics, neural-network predictive algorithms, and expert systems.
Workflow to Automatically Update Geological Models during Well Placement with High Angle and Horizontal Well Log Interpretation Results
Authors: Omeragic Dzevat , Polyakov Valery , Shetty Sushil , Brot Benoit , Habashy Tarek , Flugsrud Tor Livar 
Published: March 2013

Abstract
We present a novel methodology for integration of high-angle/horizontal (HA/HZ) well data into 3D geomodels as a natural extension to well placement workflows. Log interpretation, typically done in 2D cross-sections, is based on 1-D automated inversion, yielding near-wellbore reservoir structure and properties. 2D cross-section, updated by inversion and further refined using 2D/3D modeling, is subsequently retrofitted into the geomodel so as to minimally perturb the original topology. Changes in positions/dips/azimuths of boundaries and faults, cell properties, and further local grid refinements are applied automatically. The updated geomodel honors high-resolution logs and low-resolution seismic/nearby wells data.
We demonstrate this on a typical real-time well placement scenario. Electromagnetic log interpretation codes are integrated as a high performance computing (HPC) Web service into a geosteering/model update workflow. As the initial model, we use 3D geomodel constructed from seismic/vertical well data. A "curtain" cross-section is extracted, edited based on 1D inversion, and further refined to match HA/HZ logs through 2D and 3D forward modeling, by changing properties/dips/layer thicknesses /fault positions, while preserving the original topology. Then, updated node coordinates and cell properties of the affected pillar grid region are calculated to optimally retrofit the changed 2D cross-section into the grid. These changes are then automatically applied to the 3D model. For quality control, we recompute the 2D cross-section from the refined geomodel. Ultimately, we arrive at the geomodel that honors both seismic and resistivity well-log data. The combination, in a single workflow, of physics-based log modeling codes, Services-Oriented Architecture, HPC framework, and the solver to optimally retrofit 2D cross-sections into 3D models, creates a qualitatively new opportunity for well placement engineers.
This integrated workflow (1) maximizes the value of deep directional resistivity well-logs and real-time well placement interpretation by incorporating them into the source of data for building geomodels; (2) radically speeds up the model refinement loop by automatically calculating and applying the modifications to 3D reservoir model; (3) enables geoscientists to directly refine geomodels while geosteering. The latter has not been a standard practice, hindered by challenges of scale difference between geomodels and well-logs and lack of availability of efficient modeling codes.
What are We Going to Do With All These Wells Then?
Authors: Cramer Ron 
Published: March 2013

Abstract
Advances in drilling technology (e.g. fracing, horizontal wells) has led to successful development of onshore shale gas, tight gas, coal bed methane, shale oil and burgeoning well numbers. Some Majors have indicated that they will drill up to 20,000 new wells by the end of the decade. To achieve well numbers and cope with the work load and manpower shortages, drilling automation technologies are being introduced that will allow multiple rigs to be operated remotely and downmanned.
It is premised that well production operations will also have to be automated to cope with increasing work load as resource will not be available to operate these wells in the traditional, manual way. Associated production processes that will have to be automated include, well surveillance/optimization, well testing, sampling, chemical injection and hydrocarbon accounting. It is desirable to bring the wells onstream as soon as possible after drilling and to maintain production rates at as high a level as possible and to simultaneously account for production of oil, gas and water. It also is imperative to ensure the highest level of safety and environmental factors.
Hence, the purpose of this paper is to describe well automation business requirements/benefits and potential system solutions to optimize production over the life cycle for the ever increasing number of onshore wells that will be drilled in the near future.
Automatic Sensor Data Validation: Improving the Quality and Reliability of Rig Data
Authors: Ashok Pradeepkumar , Ambrus Adrian , van Oort Eric 
Published: March 2013

Abstract
Bad quality data is ubiquitous in oil well drilling operations. The hostile and uncertain environment in which sensors are used and the lower priority/importance usually given to regular calibration of these sensors to ensure accuracy are the main reasons for the lack of good quality and reliable data. Today, online streaming of sensor data from at least all the primary sensors on a rig to a real-time data monitoring facility is becoming commonplace. There also exists software to analyze this data, in real-time, to detect trends and identify potential drilling problems long before they occur. However, these software applications require good quality data to perform accurate analysis. When data is not validated, false and missed alarms are the norm whereby supposedly autonomous software applications require continuous human supervision. High quality data will also be required in the near future when adopting control algorithms for rig automation, which will use this data for making autonomous, closed-loop decisions.
In this paper, a novel technique for real-time sensor data validation is proposed that improves the quality of data collected from the sensors on a rig. This technique uses a model-based approach and the principle of conditional independence. Here, a sensor probabilistic graphical model is created and the relational redundancies in the model are exploited to differentiate between a sensor fault and a process fault as well as to identify the faulty sensor. The approach described in this paper allows for model update in real-time to account for process degradation/changes, thereby alleviating problems associated with the use of a purely analytical model. The application of the algorithm on a generated data set and the results of the experiment are presented in this paper. The adoption of such techniques is expected to greatly enhance the safety and the performance of well drilling and pave the path forward for more automated rig operations.
Exploiting the Latent Benefits of Wired Pipes: A Comprehensive Decision Making System
Authors: Yazidi A. 
Published: March 2013

Abstract
The invent of wired pipes technology opens new avenues for decision making in drilling operations while rising new challenges for making sense of the deluge of delivered measurements. Due to the high costs of drilling, fastness and safety are the two most forsaken requirements. The wired pipes technology inaugurates a dramatic change in the way drilling is currently performed. In fact, down-hole measurements will be available at a higher data rate alleviating the need for the traditional model based measurements, different sensors will be distributed along the miles of pipe posing challenge to fusion them for decision making. In addition to handling the overwhelming quantity of information, user friendly human machine interfaces should be developed and the driller should be trained to cope with the new ways of presenting the drilling data. Exploiting the latent benefits of wired pipes requires an interdisciplinary research that combines different fields of science namely data mining, control theory, artificial intelligence and statistics. In this paper, we will give insights into our effort centered on devising a comprehensive real time decision making mechanism that resorts to wired pipes. The main idea behind is to automatize many of the manual operations in drilling so that to achieve higher speed drilling. The paper will mainly focus on optimizing the rate of penetration, the control of pressure within the pressure window, optimizing the tripping in/out speed and managing the pump start-up. Accurate estimation methods of the remaining life of the drilling bit should be developed in order to avoid unnecessary tripping. The paper will also give insights into Artificial Intelligence based paradigms for predicting and detecting drilling incidents such as loss of circulation and hole pack-off.