bluuebunny/crossref_metadata_2025_split huggingface dataset:
History-Matched Reservoir Model Validation Based on Wavelets Methods
Authors: Kind Martin V. , Quinteros Javier 
Published: December 2007

Abstract
Many predictive methods based on numerical simulation generate undesired changes on the distribution of their parameters that depend mainly on the numerical method or the grid orientation (artifacts). On the other hand, it is common to find an appropriate match of the production history through the use of reservoir properties as calibration parameters, even when this procedure generates in many cases geological inconsistencies. Also, as real time data acquisition is becoming a powerful and popular technique, it is important to achieve a methodology that allows the input of new sources of information without disturbing the history matching previously validated.
In this paper a new methodology to integrate a history-matched reservoir model with other geological data is presented. It is based on the methodology proposed by Sahni and Horne1, that based on the Haar wavelet transform allows for the improvement of the history-matched geological model through the inclusion of additional geological constraints without needing to perform the history matching every time the reservoir model is updated.
The first step of the method presented in this study is to match the production history of the reservoir that will be modeled by means of numerical simulation. Then, the wavelet function that better fits the distribution of the considered properties, keeping the highest Energy Compaction Ratio (ECR), is chosen. After performing the wavelet transform, the most sensitive coefficients to the production data are determined. Those that are not significant for the model validation can be modified and geostatistical interpolation algorithms can be applied (e.g. Sequential Gaussian Simulation). Finally, when the inverse transform is performed, the data set is not only validated by the production history but also by the geological properties.
If the wavelet transform is not Haar, an additional benefit is obtained. It is possible to interpolate the geological information in the different regions where the data acquisition is difficult or doubtful.
This new heuristic methodology has been tested in different reservoir configurations. In this paper, we validate the results achieved for a test case reservoir with patterns of 4 producers and 2 injectors. This procedure is very helpful in numerical simulation of reservoirs and it has a direct impact on its management, risk analysis and the development of depletion plans.
Novel Frac-and-Pack Technique for Selective Fracture Propagation
Authors: Hidalgo O. , González O. , González V. , Sánchez A. , Peña A. 
Published: December 2007

Abstract
Frac-pack is a pervasively used completion technique in wells targeting high permeability, poorly consolidated and depleted sandstone formations located in Bachaquero, Tía Juana and Lagunillas fields in West Venezuela. This technique combines stimulation and sand production control in a single treatment by placing a short and wide fracture which bypasses the near-wellbore damage, while gravel-packing the zone of interest.
This paper describes a novel and economical frac-and-pack technique which consists of pumping a sand plug with the downhole tool set for circulation to isolate a bottom set of perforations, followed by conventional frac-and-pack. When this procedure is followed, the fracture is forced to propagate along the upper intervals. This novel technique is particularly useful for wells with water-producing zones near the bottom of the target zone, because it induces selective growth of the fracture along the upper intervals and mitigates the risk of growing the fracture into the water-producing zone.
A case study of a frac-and-pack performed in a Lagunillas field well with a water contact 40 ft below the target zone is reviewed. The intervention rendered an increase in well production rate from 27 to 173 net barrels per day with a reduction in water cut from 25% to 9%. In contrast, two wells in the same field and with very similar characteristics which were frac-and-packed conventionally rendered 100% and 63% water cuts, respectively.
Another application of this technique refers to frac-and-pack of wells with long perforated intervals where early wellbore screen-out may occur due to proppant bridging of the annular volume between the screen and the casing. Conventional frac-and-pack of twenty wells in these fields with perforated intervals exceeding 90 ft rendered a 40% early wellbore screen-out rate. The early wellbore screen-out rate was reduced to 12% in a sample of twenty eight wells with the new technique. The average production rate increased from 2 to 135 BOPD, whereas the average estimated after-treatment production was 130 BOPD, for which this technique was considered successful. A shortcoming of the technique for this application is the fact that the bottom of the perforated interval is not fractured. High-end frac pack techniques that overcome this issue such as use of shunt tubes were found to render higher normalized oil production rates.
Casing Drilling Connection Qualification for Shell Rocky Mountain Project
Authors: Lu Qing , Hannahs Dan , Buster Jerry , Coe David , Langford Steve 
Published: December 2007

Abstract
Shell has operations in Pinedale Anticline, Wyoming. Most wells in this region are approximately 14,000 ft deep and take an average of 30 - 40 days to drill. Drilling within their 4 1/2" production tubing strings will allow deeper penetration into the production zone resulting in increased production. To reduce well cost, Shell requested Grant Prideco to qualify the 4 1/2", 13.50ppf, P110 DWC/C-SR to utilize for its production string. This paper details the specific test plan.
DWC/C-SR is a thread seal connection which has been integrated with a resilient seal. Both fatigue and seal ability performances were to be verified because the connection will be used for drilling applications. Fatigue testing followed API RP7 guidelines. Seal ability testing was based on ISO 13679 qualification requirements.
Finite element analysis (FEA) was performed on different ISO configurations to determine the worst-case fatigue configuration based on linearized Stress Amplification Factor (SAF) analysis. In addition, FEA was used to determine the worst-case galling configuration. Three specimens were tested at targeted stress levels to determine the connector fatigue life. Next, four specimens were fatigued to a pre-determined number of cycles at a target stress level. This was followed with ISO series B tests. In order to evaluate high temperature performance, one of the ISO Series B test was conducted at 300°F. Additionally, make/break specimens were tested to verify galling resistance.
Casing drilling technology is quickly expanding into more stringent applications. However, connection performance under these severe fatigue and combined load applications is uncertain. Previously, casing drilling connection design focused on providing high torsion capacity and fatigue resistance; however, sealability characteristics should be seriously evaluated. The test program detailed in this paper evaluates connection performance for both fatigue and sealability. This information will assist in facilitating a broader application of casing drilling connections.
Reducing Drilling Risks in Highly Overpressurized Formation: A Case History in Nororiente Basin, Argentina
Authors: Frydman M. , Restrepo J. D. , Palacio J. , Airoldi C. , Eguia H. 
Published: December 2007

AbstractDifferent oil operators have faced technical and economical challenges while drilling wells in the Nororiente basin. Drilling in a tectonic active setting creates problems ranging from influxes and stuck pipe incidents to circulation losses and reservoir damage. Operations in Ramon Lista experienced similar problems, especially wellbore instability, lost circulation and influxes. The presence of a salt member increases the drilling risks, with very high pore pressure (up to 19.3ppg) just below this member. Drilling nearby wells has evidenced many catastrophic events, like 120 days to control an influx with simultaneous losses. This article will describe the application of the process used to reduce risks and cost while drilling in the Nororiente basin.
Value-of-Information Applications In Unconventional Resource Plays
Authors: Leach Patrick E. , Brown P. Jeffrey , Haskett William J. 
Published: December 2007

Abstract
Unconventional resource plays (e.g., tight gas plays, coal-bed methane, etc.) play an increasing role in the global energy budget. Those in the United States have attracted a lot of attention and study in recent years, but for many of the international unconventional plays, information regarding likely production rates, ultimate recoveries, development costs, and the overall profitability of these plays is often exceedingly scarce. As such, companies interested in pursuing these plays must make decisions regarding what information to acquire. Seismic surveys, regional studies, exploration/appraisal wells, pilot programs, etc. – all are possible sources of data regarding the ultimate behavior of the reservoir. Unfortunately, all are possible wastes of money and manpower, too.
Maximizing the probability of financial success in these plays requires a thorough, consistent value-of-information (VOI) process. This paper presents an approach that emphasizes estimating the reliability of these information sources in a consistent way, including performing sensitivity analyses to see how the VOI changes by varying input parameters (including reliability).
Results can give the decision-maker confidence in the decision to acquire information (or not to do so), and yield insights into the overall profitability of the venture. They also highlight those uncertainties that merit further attention, versus those that can be ignored (or must simply be accepted) for the time being.
In the absence of VOI analyses, the value of highly uncertain opportunities can be grossly mis-estimated. Such analyses should play a key role in estimating the profitability of unconventional resource plays.
Effective HSE Management and Auditing System Guarantees Results
Authors: Mahfouz Mamdouh , Rashwan Abdel Razek 
Published: December 2007

Abstract
The oil and gas industry prides itself on having some of the best safety records compared to many industry sectors. Health, safety and environment (HSE) became a familiar term and number one consideration in oil and gas industry. Nevertheless, traditional HSE manuals, bulletins & instructions are not enough to guarantee that the system is effective and serving the organization. Well structured safety policies, training and employee handbooks are the norm but for a safety policy to have any relevant meaning HSE values cannot remain as words on paper, they must be taken up and used by employees and translated into performance.
It became mandatory to the industry to find a way to make sure that HSE instructions reach every employee and accurately implemented. This could only be achieved if proper auditing is employed. Proper auditing for a professional HSE system can definitely close the loop and fill the gap between what is written in manuals and what is eventually implemented. In the mean time, while establishing your HSE system make your reference one of the recognized international standards known to most of companies. This will make the language of your system familiar to others and help auditors when reviewing the system.
Before you start, a team of experts must be formed to sponsor this task. Team members must be solicited from different company disciplines to cover all potentially hazardous areas. The team will thoroughly consider the following areas when designing the project; equipment reliability, maintenance standards, operations procedures, emergency preparedness, proper documentation and people.
Candidate Selection for Underbalanced Drilling: An Approach
Authors: Rehman Shaikh Abdul Mujeer Abdul 
Published: December 2007

Abstract
Underbalanced drilling is often done to reduce formation damage, avoid lost circulation problems, stuck pipes, etc. Thus, there has been a growing acceptance for underbalanced drilling. By far, it has also been proved that the advantages of underbalanced drilling are most evident in depleted reservoirs. Though there are some challenging issues with UBD such as bore hole instability problems due to the lack of positive support from the bore mud, these issues can be dealt with the evaluation of in-situ stresses and a realistic estimation of formation rock mechanical properties. Thus the above two factors and proposed borehole trajectory and mud weight design play an important role in avoiding borehole instability problems and achieving the field objectives.
Candidate selection is the key to the success of underbalanced drilling (UBD) projects. The question to be answered is why sometimes UBD significantly improves productivity compared with conventional overbalanced drilling (OBD) practices but sometimes it doesn't. To answer this question, an extensive reservoir engineering study to understand the mechanisms of productivity improvement from UBD must be performed. A single-well model can be built that simulates the UBD process and the OBD process (while taking into account drilling filtration invasion, mud cake, and permanent formation damage) and their impact on production under a variety of reservoir conditions. Production rates should predicted for both UBD and OBD cases. Then, a model should be used to analyze the economic benefits of UBD operations (if any) for the given reservoir.
Reservoir properties play a role in the success of UBD operations. The study would clearly demonstrate that UBD works for some reservoirs but not for all reservoirs.
The study results would provide a set of reservoir criteria that can be used as guidelines to choose potential UBD reservoir candidates.
Successful Application of Novel Cementing Technology in Hassi-Messaoud, Algeria
Authors: Bouras H. , Toukam E. , Martin F. V. , Bedel J. -P. 
Published: December 2007

Abstract
The ultimate objective for cementing a casing string is to achieve long-term integrity of the well. This can be achieved through long-term zonal isolation between the penetrated formations with appropriate mechanical properties, low permeability, and shear bond strength properties provided by the cement sheath placed in the corresponding annuli. Experiences in the Hassi-Messaoud field have shown that zonal isolation is a very complex problem for some formations such as the LD2 zone, which exhibits, in some cases, corrosive fluids and highly saline formations as well as lost circulation zones. Cementing operations are critical and the need for cementing systems capable of solving these problems is crucial.
This paper focuses on the factors that have contributed to the potential failure of the existing cement system. Stress modeling has been used to select the appropriate cement system to overcome the challenges faced by the cement sheath in this type of environment. Stress analysis calculations, combined with mechanical properties testing of the cement system, has suggested the use of a novel cementing technology. This new system has been able to solve these problems to provide flexibility, improve corrosion control, expansion properties of the set cement, reduce the chances of microannulus creation, and therefore avoid overpressurization of the annulus casing. To ensure correct cement placement in the lost circulation zones, this slurry system has been successfully combined with fibers specifically engineered for cement slurries.
This technology has been a cost-effective solution for cementing 12 1/4-in sections in the Hassi-Messaoud field and 8 1/2-in sections in the Berkaoui and Hassi-Guettar fields. Field results have proven that significant workover costs, up to USD 1 million on wells in production, can be saved with the application of this technology.
One-Trip Installation of 4¾-in. Expandable Screen Assembly
Authors: Mohamed Omar Y. , Waters Ray , Attia Ahmed , Pierfelici Stefano , Abdelaaty Petrobel Gharib , Ripa Giuseppe 
Published: December 2007

Abstract
Expandable metal technology applications can provide cost-effective solutions to drilling and production challenges.
One such application is expandable sand-control screens that eliminate annular flow and help prevent sand migration and "hot spotting." A recent project with our partner Petrobel (operating company joined between ENI and EGPC) employed a Baker Oil Tools expandable screen assembly to recover reserves in the offshore Mediterranean Sea North of Port Said City.
The aim of the project was to install, in one trip, the 4-¾-in. Expandable Screen Assembly in Well PFM-8 in order to isolate shale layers above and below the 4 MT thick gas bearing sand in a 6 inch open hole. The Expandable Screen Assembly design combines sand control with expansion technology, providing formation particle exclusion, annular flow reduction, hole stability, and large inside diameters (IDs).
Upon conclusion, the project yielded very positive tangible results: Production was 1.8 MM m3/d and likely to increase after further cleanup. The first run of 4-3/4-in. Expandable Screen in Egypt offshore the Mediterranean Sea has been successfully in well PFM-8 for Petrobel. The success was not only in flawless installation, but also in sustaining long terms sand-free gas production at 1.8 MM m3/d and more than 2000 bbls of associated condensate from 4 MT thick reservoir in 6" open hole.
This paper will explore the successful completion technique used in Egypt, using Expandable sand-control technology.
Integrating People, Plant, and Process in the Design and Operation of Process Industry Assets.
Authors: Hamilton W. I. , Cullen L. , Reeves G. 
Published: December 2007

Abstract
The fatal explosion at the Texas City Refinery in March 2005, highlights the importance of comprehensively addressing human factors during project design to avoid catastrophic consequences. While many factors contributed to varying degrees to cause the explosion, BP’s response to the explosion included developing a comprehensive procedure and supporting guidance on the integration of human factors with project engineering processes.
Other sources of such guidance do exist but they are generic in that they do not map onto an engineering or systems development process. Or they are specific only to certain stages of development. This work is original in its attempt to create a comprehensive solution to oil and gas projects’ development cycle, and in trying to map this onto an operating Company’s management systems.
This paper reports on the work undertaken to develop a human factors integration procedure for BP’s projects and operational management. It describes the requirements gathering and drafting phases of the work, and shows how the description of human factors practices has been tailored to the organisation’s established engineering and technical safety management systems. The human factors process model has been validated with stakeholders throughout the organisation and in support of a major project. The results of these validation activities are reported here.
Tracing Groundwater Pollution in the Oil Industry: Myths and Reality
Authors: Ostera H. A. , Torres C. , Fasola M. 
Published: December 2007

Abstract
During the last years, a complete set of brines, groundwaters and surficial waters surveys was carried out in oilfields in order to determine the presumed oil born contribution to the groundwater pollution. The survey included the most important basins in Argentina and a wide variety of geological and hydrogeological conditions. Although conventional hydrogeochemistry played an initial role, the isotope tool has been the key for unravelling some delicate and doubtful cases. Most brines are very well characterized by their isotope composition and high salinity, leading to an easy recognition in the case of mixing. Besides the stable isotope composition of oxygen and hydrogen, tritium and Sr isotopes helped to model the interaction of production waters, groundwaters and surficial waters. As a matter of fact, and except for some old passives, the results showed that the improvement and change in water managing practices during the last decade avoided major problems. Despite this situation, the lack of knowledge on the new practices of oil industry and a high degree of incredulity from the people, limits the appreciation of this improvement to the courts and specialists. A thoroughful campaign to clarify the results, utility, confidence and limits of a multitracer approach is necessary to face the public concern in order to demonstrate that the oil activity can be environmentally friendly and that the water resources are a common heritage that will be preserved.
Optimized Drilling Cost Per Foot in KPC Versus the Increase of Drilling Tangible and Intangible Cost (Case Study)
Authors: El Bakly O. , Ali K. , El Dawey M. 
Published: December 2007

Abstract
KPC challenges was and still to maintain the lower cost per foot in western desert of "Egypt" using a competitive solutions and designs to overcome increase of drilling materials & services costs in structures with low productive reservoirs.
This wasdone through customizing the following parameters:
Using slick BHA rather than stiff BHA which improved rate of penetration for western desert's formations (Doubling ROP) associated with good Hole trajectory. Improving casing design to minimize number of casing strings, exposing long (Stable) open hole sections while drilling. Reviewing & enhancing drilling mud systems to maintain good hole stability through long deep open hole sections (+/- 11000 FT exposed section). Optimizing bits usage to be compatible with drilled formations. Reviewing cement designs to cover low fractured formations, using low cost high quality cement to overcome gas migration by optimizing transition time. Optimizing rigs fleet and maximizing rigs utilization to perform drilling & workover wells effectively & safely. The use of slim hole design.
In this domain, KPC presents its experience in reducing the cost per foot. KPC's obtained cost/ft was proven to be the lowest cost all over Egyptian westetrn desert compared to sister companies in same area, wherever, the wells below 8200 ft have an average of 50 US$ versus 60 US$, wells between 8200 ft and 13100 ft achieved 140 US$/ft versus 175 US$, wells more than 13100 ft achieved 185 us$/ft versus 265 us$/ft.
It is concluded that, it is not necessary to depend only on the new technology for achieving lower drilling cost per foot, but it is as well as important to adapt the drilling techniques to desired requirements.
The Evolution of Communities of Practice in a Petroleum Services Organization
Authors: Smith David L. 
Published: December 2007

Abstract
Most knowledge management implementations include communities of practice or networks which allow people to connect to other people, share ideas and discuss issues. Communities have been shown to be informative, solve business problems, and create innovative solutions. They are usually focused around disciplines, projects, products, services, or general issues. Unfortunately, companies find the majority of their communities have little to no activity, do not show sustainable results or demonstrate any measure of business impact.
Only a very few knowledge management (KM) implementations produce true business value, and the oil industry is no exception. In fact, the April 2004 issue of CIO magazine1 noted that "85% of all KM initiatives fail". We can only assume that the communities of practice in these implementations are not creating value.
This paper will detail the evolutionary changes in communities of practice within a petroleum services company. We will look at changes in community audience, facilitation, and leadership along with the actions taken to ensure that the KM communities create value.