bluuebunny/crossref_metadata_2025_split huggingface dataset:
Engineering Workflows for Production Surveillance and Optimization
Authors: Farid Kemal , José A. , Alvarez Cheo 
Published: December 2007

Abstract
This paper examines the growing need for workflow management in the upstream production industry. Workflow management is the management and improvement of data and activities through specific business, scientific, or engineering processes. This paper discusses the application of workflow management to upstream production surveillance using software that can integrate large data volumes with multiple engineering tools.
Engineering workflows can provide new and improved analytical capabilities that are applicable to a wide range of tasks, including field development planning, production deferment tracking, and assisted model creation, among many others. Effective workflow management is associated with multiple benefits, including knowledge retention when older employees leave the workforce, knowledge transfer, and process automation that results in the more cost effective management of production assets. Engineering workflows can automate field surveillance by combining production models with access to multiple data sources.
As an example, we present the use of a model-based surveillance-by-exception workflow to produce timely, actionable data for proactive field management. This worfklow also serves as an excellent model of how the integration of data, tools, and processes can be better achieved through workflows.
Gas Productivity Enhancement by Wettability Alteration of Gas-Condensate Reservoirs
Authors: Al-Anazi Hamoud A. , Xiao J. J. , Al-Eidan Ahmed A. , Buhidma Ismail M. , Ahmed Mahbub S. , Al-Faifi Mohammad G. , Assiri Wisam J. 
Published: December 2007

Abstract
Gas condensate reservoirs experience significant productivity losses as reservoir pressure drops below the dewpoint due to condensate accumulation and the subsequent reduction in gas relative permeability. One potential way to overcome this problem is to alter reservoir wettability to gas-wetting to reduce condensate accumulation in the near-wellbore and maintain high productivity. The aim of this study was to evaluate the effectiveness of various chemical treatments in altering wettability of gas-condensate reservoirs from liquid wetting to intermediate gas wetting. Coreflood experiments were conducted on carbonate and sandstone reservoir cores and Berea cores at simulated reservoir conditions. Several chemicals (fluorochemical and silane) were screened in this study to determine their capability in removing the trapped condensate from cores, enhancing gas relative permeability, and delaying condensate accumulation. The results of coreflood tests showed that the effectiveness of fluorochemical surfactant is affected by treatment volume, aging time, core permeability and temperature. Sandstone cores treated with 1.25 wt% silane chemical showed repellency to liquids (water and condensate) and an enhancement (up to 42%) in gas relative permeability. It was found that core permeability plays a role in wettability alteration agents' effectiveness. Wettability tests showed that contact angle on treated cores is 116° for water and 114° for condensate, indicating wettability alteration from liquid to intermediate gas wetting. Environmental Scanning Electron Microscope (ESEM) analysis performed on silanes-treated cores gave a conclusive evidence of wettability alteration at the pore scale.
Case History: Application of CHI Modeling® Using Pulsed Neutron To Create Pseudo-Openhole Logs in Highly Deviated Wells Using Special Techniques for Logging and Perforating in Veracruz, Mexico
Authors: Reed Skip , Torne Juan Pablo , Pacheco Erick , Augusto Lara , Casillas Zenon , Palacios Cesar , Riaño Juan Manuel , Corral Aguirre Alejandro , Casares Martin , Simon Jose D. , Arteaga Rafael 
Published: December 2007

AbstractThe Veracruz basin, located in eastern Mexico, has sometimes been very difficult to evaluate with openhole wireline tools because over-pressured gas formations present a problem when trying to reach a balanced borehole condition. One of the fields was planned for development using nearly horizontal wells to maximize production, but acquiring openhole logs in these wells has proven to be difficult.Well A-21 is the first highly horizontal well to be completed using only LWD resistivity data in the nearly horizontal section. To assist in the evaluation after the well was completely drilled and cased, a pulsed neutron tool was logged across the entire well using a tractor device to reach the total depth of the well. An evaluation model for the A field was then developed using the CHI (cased hole interpretation) modeling program, by using the openhole resistivity and porosity data acquired in the vertical A-1 well, combined with the cased hole pulsed neutron data acquired across the same interval. Pseudo resistivity and porosity logs were then created for the A-21 well using only the pulsed neutron data acquired across the nearly horizontal section of the well, based on the Chi Model developed for the field. The pseudo resistivity was then compared to the LWD resistivity data acquired in the A-21 well. Next, the interpretation was completed by defining the optimum perforating interval for the reservoir conditions and the mechanical condition of the well. After evaluating the interpretation, the On-Balance perforating technique using coiled tubing was decided upon as the optimum technique to perforate the A-21 well, to minimize reservoir damage. This paper will present the procedures used to evaluate and complete the A-21 and the A-31 wells, as well as a comparison of the CHI Modeling pseudo resistivity with the LWD resistivity measurement.The use of pulsed neutron logs to acquire pseudo openhole data is shown to be a valid alternative when drilling conditions do not permit normal data acquisition in openhole. The integration of the data obtained, along with applied reservoir geomechanics, for perforating design and production planning is shown to be a valid alternative to maximize production, and to prevent sanding and completion problems while reducing costs.
How To Select PDC Bit for Optimal Drilling Performance
Authors: Nygaard R. , Hareland G. 
Published: December 2007

Abstract
Selecting bit when you have multiple bit vendors giving their proposal can be a challenge for the operator. To justify the bit selection can be hard for the drilling engineer in a multiple vendor situation. The purpose of this paper is to show a systematic approach on how to select PDC bit based on quantitative measure by using a simple scorecard. When the drilling organization has agreed on the overall drilling objective for the well a scorecard is used as decision criteria for selecting bits. To quantify the input for each bit a drilling simulator was used. The simulator can, based on a rock strength prognosis for a well, predict the rate of penetration and bit wear for each bit based on the bit design. For other criteria which are more difficult to obtain e.g. ability to create dog leg a qualitative ranking was used. In the two field examples shown from the North Sea the method has worked well to give a reliable and transparent bit selection method. Using a scorecard also reduced the ambiguity among the bit company representatives on how the selection process was done.
Improved Drilling-Process Control Through Continuous Particle and Cuttings Monitoring
Authors: Omland T. H. , Saasen A. , Taugbøl K. , Dahl B. , Jørgensen T. , Reinholt F. , Scholz N. , Ekrene S. , Villard E. , Amundsen P. A. , Amundsen H. E. F. , Fries M. , Steele A. 
Published: December 2007

Abstract
Major advancements have been made in the past decades to determine the effects from particle additions to drilling fluids. These additions affect wellbore stability, hole cleaning, sag stability, formation damage and back-production capabilities. Furthermore, optimum drilling fluid performance is strongly dependent on knowing the properties of the formation such that correct selections of drilling fluid additives can be made. Likewise, it is important to know if produced solids are drilled cuttings or cavings originating from unstable holes.
In field applications, there has been reluctance towards trusting solids control equipment as the only method for controlling the particle size distribution (PSD) and particle content of the drilling fluid system, since no real-time monitoring equipment has been available to produce the necessary measurements. The present paper describes a technique based on image analysis, which makes it possible to obtain such information in real-time. The method also provides valuable information for characterizing drilled cuttings, creating the basis for caving logs. A method for obtaining mineralogical data from the formation by analyzing the drilled cuttings by using Raman spectroscopy is also described. Field tests and laboratory studies demonstrate the potential of the techniques for improved drilling process control by continuously monitoring the particles in the system while drilling. Some of the elements in a drilling fluid process which are affected by the presence of particles are also described.
A New Tool for Exploration and Appraisal—Formation Damage Evaluation
Authors: Byrne Michael , Patey Ian , Green Justin 
Published: December 2007

Abstract
Formation Damage can be defined as any near wellbore alteration that affects permeability due to well operations. Use of any tool(s) to avoid or rectify formation damage may be helpful in terms of reducing costs or improving hydrocarbon recovery. These tools may either indicate or predict the changes in near wellbore permeability, and may identify the cause and suggest alternative well operations and/or specific remedial treatments to improve hydrocarbon recovery. A new tool has been identified to realise and help unlock the hidden potential of marginal fields at the exploration and appraisal stage. This is a tool based on multi-criteria decision analysis that combines the use of pre-existing geological and reservoir conditions core flood laboratory analysis, which predominantly compares datasets before and after simulations of well operations to enhance formation damage evaluation and assist in making cost benefit descisions. Existing geological and well data can be combined with a comprehensive formation laboratory study, to effectively create a new tool which, based upon multi-criteria decision analysis, can assist in making cost benefit decisions.
The majority of formation damage laboratory testing is performed during field development in order to determine the least damaging drilling, completion and injection fluids and procedures. This analysis has now become routine and is part of field development planning for most major operators. Formation damage evaluation should also be conducted at other times in the life of a field or well. The reservoir can be damaged or can suffer damage mechanisms throughout its exploration, appraisal and development history. By understanding damage from the day the first drill-bit penetrates the field we can develop a greater understanding of reservoir potential. Full simulation of drilling, completion and production of exploration and appraisal wells can unlock hidden potential in marginal fields.
Examples of the impact of formation damage on well performance and some examples of formation damage investigation and remediation will be discussed. Specific examples of how formation damage has been used to re-value potential of marginal discoveries and has led to successful development will be presented.
HPWBM as a Technical Alternative to Drill Challenging Wells Project: Lessons Learned in Deepwater Brazil
Authors: Ramirez Mario A , Moura Eliabe , Luna Edgar , Aragao Atila , Taira Helio 
Published: December 2007

Abstract
Traditionally, Non-Aqueous Fluids (NAF) have been used by a major operator to drill challenging wells in the Campos Basin, Brazil. Significant advances in water based drilling fluid design in the recent years have allowed water-based drilling fluid performance to approach that of NAF. Exploration in the new frontiers and optimized development well projects in deepwater Brazil have required a different approach regarding drilling fluid design due long step outs, difficult well trajectory, and the possibility of drilling horizontal wells in one step, thus avoiding intermediate casing strings. Although NAF are an ideal candidate for those applications, environmental concerns and logistic demands are still an issue and alternatives should be considered.
HPWBM has been applied to replace NAF in some applications in deepwater and ultra deepwater (UDW) in the Campos Basin. This novel technology has been successfully applied to drill in UDW scenarios, reactive clays, dispersive shale, naturally micro fractured formation and horizontal wells. HPWBM characteristics are developed with: 1) A new generation of encapsulation polymers; 2) The use of amine chemistry to provide clay stability; 3) The application of novel sealing polymer for shale stability; and 4) Excellent mud lubricity characteristics.
The lessons learned, as supported by case histories and lab data have contributed to system modifications which have improved performance. This work has also identified attributes needed to complete a drilling fluid design for the difficult wells to be drilled in the new exploration and development areas. The evolution of HPWBM drilling fluid design will be discussed along with how decisions were made.
Managing Risk and Uncertainty in the Visualization of Production Scenarios
Authors: Saputelli L. , Mijares G. , Rodriguez J. A. , Sankaran S. , Garibaldi L. , Revana K. 
Published: December 2007

Abstract
Field development decisions must be made despite uncertainties of well performance, subsurface response, equipment failure rate, and downstream demands. The heterogeneity of information and complexity of current hydrocarbon assets implies an iterative approach to identify opportunities, which requires risk and uncertainty management. To accomplish such a challenging goal, it is necessary to estimate requirements for surface facilities while considering both reservoir uncertainties and multiple development scenarios, and their link to the economic model.
Optimizing production operations may involve identifying opportunities for production increase from reservoir, wells, and surface equipment with the minimum effort. In addition, to make robust planning
This paper presents methodologies, technology applications and case-studies for managing risk and uncertainties in the visualization of production scenarios. They are shown examples of multiple reservoir forecasts with wells and surface facilities network models and operational issues, such as well performance, subsurface response, equipment failure rate, and downstream demands.
We show several integration procedures for handling reservoir production uncertainty, well performance, drilling schedule compliance, workover success, and varying surface facility variables, such as availability, uptime, and capacities. The examples shown in this paper permits the visualization of a more realistic short-term asset performance while minimizing requirements in the long-term, minimizing risk and manging uncertainties.
Leverage Knowledge-Management Tools To Better Understand and Meet the Needs of the Industry
Authors: Paylow K. , Hickman A. , Liu S. , Guidry A. , Zappa D. 
Published: December 2007

Abstract
To meet the long-term technology and performance needs of the upstream industry, the present and future market must first be understood and then acted upon. A collaborative knowledge management (KM) system complements other market assessment tools by harnessing the collective capability and experience of an organization's employees to more effectively identify, communicate and act on customer needs, market knowledge and potential solutions.
While many companies' KM efforts are focused on technical problem solving and/or employee development, a KM system can also be used to develop better organizational and individual understanding of, and more importantly, adaptation to the market. Any employee can initiate or participate in collaborative communication to actively share and discuss customer needs, competitor activities, new technology applications and successes. Any employee can submit ideas for new or improved products to meet their local market needs. Where appropriate, these ideas are collaboratively reviewed, improved and validated through KM.
We use our KM system to better understand the market and drive innovation. Examples demonstrate the use of collaborative discussion to share market intelligence, clarify market assumptions, harness the ‘wisdom of the crowd’ in collecting and validating new product/service ideas and transfer technology.
KM tools and collaborative activity show promising value in improving market understanding and driving technology innovation. Halliburton broadly defines knowledge management as a systematic approach to getting the right information to the right people at the right time. Often the ‘right information’ pertains to market needs, new ideas or new technology.
Mastering Real-Time Data Quality Control—How To Measure and Manage the Quality of (Rig) Sensor Data
Authors: Mathis W. , Thonhauser G. 
Published: December 2007

AbstractThe amount of data collected in the information age has grown to amounts barely manageable. Currently available technologies are already capable of transmitting the readings of any sensor to worldwide locations at high frequencies and with nearly no time delay. With an ever-increasing flow of data, the need for criteria to measure and evaluate data quality are more pressing than ever, as this data forms the basis for many critical business decisions. This paper addresses these problems and shows essential steps to a successful data and quality management strategy:Quality control and improvement Data quality benchmarking Accessibility of controlled dataSimple but very effective signal processing algorithms are presented to ensure that the data is in the right value range, outliers are removed and missing values are substituted where possible. More complex control instances may not be able to correct data completely by automation. Here the human expert is still necessary for corrections. To minimize the work for engineers, a processing engine produces smart alarms whenever an automated data correction is not possible. If no correction is possible at all, the questionable portion of the data must be flagged invalid, or even be deleted to prevent misuse and wrong conclusions. This may be dependent on the application; so good data management is essential to provide a minimum standard for each individual case.The final step is to publish and present the data at the correct level of detail to different parts of the corporation. Key in this procedure is that every individual has easy and fast access to the data for their decision-making. In this context, the appropriate resolution, as well as the most efficient use of data processing time, is of critical interest. A unique solution to browse large volumes of drilling data is presented.
The Use of Multilateral Technology in an Environmentally Sensitive Area: The Val d'Agri Field, Italy
Authors: Caproni Cristiano , Johnstone John , Cavallaro Giorgio 
Published: December 2007

Abstract
Current trends in the oil and gas industry are focused more in operational efficiency, production optimization, value, and environmental effects than ever before. The industry actively pursues technologies and techniques that offer improvement in these areas, which explains the increased interest in multilateral well designs. In highly sensitive areas, such as national parks and areas of geographical sensitivity, it has become extremely difficult to obtain permits to prepare well sites if this preparation requires the removal of forestry, permanent scarring of the landscape, or disturbances to the wildlife or to the people who live and work in the area.
The Val d'Agri field in southern Italy is located within the boundaries of the Basilicata National Park. Consequently, Eni and its partners were challenged with reaching production targets while minimizing land disturbances. Eni evaluated and implemented multilateral technology to help meet the objectives.
The forward thinking of Eni led the company to pre-install orientation devices in the casing string during the original construction of the well. This action made it possibile to perform multilateral solutions if/when needed, such as the TAML Level 5 implemented on well Agri-1 or B.
The first orientation devices to be used were installed in well Cerro Falcone 3X or A in 2000 to construct a TAML Level 2 junction with re-entry capabilities through the completion. In 2003, the same technology was used on Agri-1 or A, where the orientation devices were installed in the 7-in. and 9-5/8-in. casings. When well Agri-1 or A was put on production, the produced fluid was found to be much more corrosive than expected. The well had to be shut in because the metallurgy of the equipment in the well was not suitable for the corrosivity of the produced fluid.
Eni and Halliburton formed a team to evaluate the situation and design a suitable solution: to exit from the 9 5/8-in. orientation device and drill a secondary lateral. This secondary lateral required a TAML Level 5 junction with an Incoloy 925 completion to isolate the junction and to provide through-tubing access to all bores, including the existing Agri-1 or A.
This paper focuses on the methodology and value this technology brought in the achievement of planned production targets.
Optimization of Stimulation Treatments in Medium-Permeability Gas/Condensate Reservoirs Using Real-Time Downhole Data Acquisition With Novel Technology of Permanent Sensors
Authors: Santillan Arturo , Inda Antonio , Steffani Octavio 
Published: December 2007

Abstract
Development of light-oil fields in Mexico is part of a strategic program to increase overall production in Mexico. Among the light-oil fields, operators have gas condensate carbonate reservoirs with medium permeabilities ranging from 3 to 10 md, with very high drawdowns. The initial development concern was how to make them produce above the bubble point. The first thought was to fracture the intervals to reduce the drawdown, but the permeability values from well tests made matrix stimulation appear acceptable. Some believe that with permeabilities in the 3 to 10 md range, fluid-loss issues may prevent reaching fracture pressure. In that case, a matrix treatment may be used, thus avoiding a more expensive hydraulic-fracture treatment.
However, step-rate test (SRT) results were unclear, so doubt remained. In three cases, permanent downhole sensors were available, and minifrac and fall-off analyses with downhole data were possible. Observation of the flow regimes in the data established a comparison of planned flow periods before and after the tests and frac jobs. If this data is used to help optimize treatment, applying frac treatments will be the best choice, and the investment will be justified. It was also observed that lower injection rates must be applied during the SRTs, starting from 0.5 bbl/min.
The operator concluded that "gray zone" candidate wells with medium permeabilities can benefit from matrix treatments and fracture treatments.
Post-fracture evaluation shows that drawdown matches very closely to the flow prediction, and this kind of reservoir can be produced above saturation points.
In this paper, three successful case histories are discussed in detail.