bluuebunny/crossref_metadata_2025_split huggingface dataset:
Lessons for Environmental Compliance From One Company's Creative Sentencing Case
Authors: Bowen F. , Van der Byl C. , Dillabough J. , Bertels S. 
Published: February 2011

Abstract
In this paper we describe a creative sentencing research project that arose from infractions at an oil sands in situ facility. We briefly outline some root causes of the infractions, key features of the industry context at the time, and lessons for regulatory compliance. While there were some contextual factors such as general industry turbulence, regulatory uncertainty related to a new technology and an industry wide personnel shortage that contributed to the conditions that resulted in these infractions; we also identify more fundamental causes of the compliance failures in this case. We find that a weak management of change process, weak operational compliance tracking and a weak culture of compliance were all at the root of this particular failure. We stress the importance of building a culture of compliance, viewing compliance as a journey and managing the cognitive load of compliance as important elements in ensuring compliance.
Applications of Micro and Nano Technologies in the Oil and Gas Industry-An Overview of the Recent Progress
Authors: Kong Xiangling , Ohadi Michael M. 
Published: February 2011

Abstract
Micro and nano technologies have already contributed significantly to technological advances in a number of industries, including the electronics, biomedical, pharmaceutical, materials and manufacturing, aerospace, photography, and more recently the energy industries. Micro and nano technologies have the potential to introduce revolutionary changes in several areas of the oil and gas industry, such as exploration, drilling, production, enhanced oil recovery, refining and distribution. For example, nanosensors might provide more detailed and accurate information about reservoirs; specially fabricated nanoparticles can be used for scale inhibition; structural nanomaterials could enable the development of petroleum industry equipment that is much lighter and more reliable and long-lasting; and nanomembranes could enhance the gas separation and removal of impurities from oil and gas streams. Other emerging applications of micro and nano technologies in the petroleum industry are new types of "smart fluids" for enhanced oil recovery (EOR) and drilling. In short, there are numerous areas in which nanotechnology can contribute to more efficient, less expensive, and more environmentally sound technologies. This paper provides an overview of the micro and nano technologies with a particular focus on nanotech-based solutions for the oil and gas and the broader energy industry. Recent developments in research in areas of significance to the oil and gas industry are briefly reviewed and include two case study examples. The potential opportunities and challenges that face future trends of nanotechnology applications in the oil and gas industry are also discussed.
Lattice-Boltzmann Method to Estimate Relative Permeabilities for Matrix-Fracture Interaction in Naturally Fractured Reservoirs
Authors: Gunde Akshay , Babadagli Tayfun , Mitra Sushanta K. 
Published: February 2011

Abstract
Oil production, enhanced oil recovery, waste disposal, and CO2 storage applications in naturally fractured oil, gas, coalbed methane, geothermal reservoirs, and aquifers are characteristically controlled by an interaction between matrix and fracture. The correct estimation of the relative permeabilities for matrix-fracture interaction is essential in the performance analysis of such reservoirs. Conventional relative permeability measurement techniques are not suitable for this type of processes as the driving force is capillary rather than viscous. An alternative to these techniques is a pore scale modeling of the process. In this study, matrix-fracture interaction by capillary (spontaneous) imbibition was numerically simulated using the Lattice Boltzmann Method (LBM). The classical LBM algorithm was modified to add the effects of capillary characteristics such as wettability and interfacial tension. The model was validated using experiments on two - dimensional sand pack models, where the strongly water-wet model saturated with oil was exposed to water to displace oil by capillary interactions. Further, LBM simulations were used to investigate the critical parameters that have impacts on relative permeabilities such as different wettabilities, matrix boundary conditions that cause co-current interaction, and gravity (vertical and horizontal interaction). Finally, the LBM results were used to generate relative permeability curves by incorporating the algorithms based on single – phase normalization techniques. The LBM images were used to quantify the saturation values. The effects of different parameters listed above on the end points and the shape of the relative permeability curves as well as the residual oil saturation were identified. The results and observations provide qualitative and quantitative data which can be used in modeling studies for naturally fractured oil, gas, and coalbed methane reservoirs.
Extended-Reach Drilling - One Run to TD
Authors: Gagigi T. , Balslev Peter V. , Hardie Jamie , Isevcan Erhan , Cockburn Colin 
Published: February 2011

Abstract
The development strategy for Qatar’s offshore Al Shaheen field involves a large number of extended-reach horizontal wells with total depths (TDs) ranging from 20,000 to 40,000 ft measured depths (MDs). Since the 2005 field development plan was initiated in May 2006, about 3 million ft of productive footage has been drilled. Drilling performance and tool reliability have been consistent challenges but have been improved to levels that enable the drilling of most sections in one bottomhole assembly (BHA) run to TD.
This paper reviews the changes made to increase drilling efficiency and to reduce non-productive time, including analysis of drilling performance for each hole section and subsequent improvement strategies. Discussions encompass the systems and processes contributing to the improvements.
The Significance of Accurate Well Placement in the Shale Gas Plays
Authors: Kok Jeffrey , Moon Brad , Han Shim Yen , Tollefsen Edward , Baihly Jason , Malpani Raj 
Published: February 2011

Abstract
Unconventional shale gas reservoirs are known for low porosity, low matrix permeability, the lack of an obvious seal or trap, large regional extent, and, in most areas, are believed to be highly heterogeneous in nature. As a result, it is common practice to confirm the reservoir thickness, evaluate the shale gas rock properties and to determine horizontal shale gas targets using vertical or pilot offset wells. Horizontal wells are then drilled and stimulated to maximize reservoir exposure and enhance inflow production performance.
Taking advantage of the high gamma ray activity found in most shale plays, a majority of horizontal wells are steered to stay within the defined target window using a non-azimuthal, averaged gamma ray measurement only. By relying on a single measurement, there is no fall back when the interpretation presents several possible scenarios. Additionally, a non conclusive interpretation will negatively impact the efforts of optimizing the learning curve across a field.
Resistivity measurements complement gamma ray data as they provide an extra data set for correlation. However, azimuthal images from density measurements acquired in real time can offer structural dip authentication along the well trajectory to provide a higher level of accuracy to the modeled structure. By having a validated structural model, a higher level of confidence in real-time steering decisions can be gained. An accurate structural model is also an effective tool to aid completion designs, correlate formation properties, refine target delineation and provide a foundation for evaluating production logs and microseismic observations.
The main objective of this paper is to demonstrate how structural modeling using only gamma ray in horizontal wells can lead to non-unique solutions that can be a potential cause of inconsistent reservoir interpretations and varied production, not only between hydraulic fracturing stages but also from well to well. Having sufficient measurements for formation evaluation, drilling and production results can be better understood and applied to enhance target selection, followed by accurate well placement within the selected target structure. This level of well placement accuracy will deliver consistent production results and provide a common platform for evaluating completion practices.
Tight Gas Multi-stage Horizontal Completion Technology in the Granite Wash
Authors: Edwards W. M. , Braxton Daniel K. , Smith Vince 
Published: February 2011

Abstract
The Granite Wash formation is a tight gas reservoir comprised of several, independent, productive horizons in the western Anadarko Basin. Each productive interval can be up to 400-ft. in certain areas. Historically, the entire 3,000-ft. package of these multiple, thick, clastic wedges has been drilled as a vertical well asset with the intent to commingle the multiple productive zones within the upper and lower intervals. Recent efforts to drill horizontal wellbores in preferential zones within the Granite Wash package have proven to be a viable exploitation alternative.
Most of the available completion technologies have been implemented with varying success, and a better understanding of reservoir performance has been linked with an increase in fracture stage capacity to drive the evolution of completion methods.
This paper exclusively addresses horizontal, multi-stage completions. Open hole, packer isolated completions as well as cased hole, perforated completions were analyzed to determine the best method of stimulation in the Granite Wash formation. Twenty-five wells drilled over the course of the last three years were analyzed with roughly half of the sample wells being open hole and the other half being cased hole.
The Granite Wash is currently considered one of the highest rates of return plays in the continental U.S. The best manner of completing these wells is subject to debate and highly controversial. The data presented in this paper demonstrates the relative success of the most common methods used and gives a recommendation for future success.
Successful Contracting of Production Facilities for Al Shaheen Field, Offshore Qatar
Authors: Cheesebrough J. S. , Messaoud Younes Ben 
Published: February 2011

Abstract
In 1992 Qatar Petroleum signed an Exploration and Production agreement with Maersk Oil Qatar AS regarding the development of the Al Shaheen field offshore Qatar. Production commenced in 1994 via early production facilities, and by late 2005, when 18 permanent platforms had been installed through earlier field development plans, the Field Development Plan 2005 (FDP 2005) was initiated.
FDP 2005 required 15 additional platforms (with a total dry weight of 125,000 tonnes), 24 inter field pipelines (with a total installed length of 240 Kms) and 5 subsea power cables (with a total installed length of 50 Kms) to be installed and connected offshore with the existing platform facilities in full production and executing a 6 rig, 163 well drilling campaign at the same time. In addition to prepare the existing facilities for the integration with the new FDP 2005 facilities, approximately 4 Million man hours of Brownfield work was required. The overall offshore work was completed with a production “up time” of 99.7%, Remarkable.
Personnel safety and environmental protection are essential and constant considerations within Maersk Oil Qatar and therefore the safety performance of FDP 2005 was a source of great satisfaction; more than 55 Million construction man hours were expended on the project, both onshore and offshore, without any fatalities and with an achieved overall LTIF of less than 0.3.
ESP Runtime Optimization - Low Volume High GOR Producers
Authors: Al-Aslawi Raed , Al-Haimer Mohammad Salem , Zahedi Alireza , Al-Khonaini Talal A. , Al-Najim Abdulaziz 
Published: February 2011

Abstract
A limitation of Electrical Submersible Pumps (ESPs) is the inability to handle significant volumes of gas. The implications of this limitation become even more critical if the fluid production rate is at or below the minimum rate required for cooling of downhole equipment. The oldest and most widely practiced method for forced convection cooling of the motor of an ESP system is to use a motor shroud. However, numerous field case studies have shown that even with the motor shroud in place, motor failure has been the primary cause of ESP failure in low-volume high-GOR wells.
The optimal mitigation solution for low-volume high GOR cased-hole producers is to lower the ESP string below the perforations, with a shroud installed for cooling of the motor. For low-volume high-GOR ESP-equipped producers that are producing from an open-hole interval installation of the same conventional shrouding system would take care of the cooling of the motor but it will not function as a free gas eliminating or reducing device. The production strings of the ESPs producing from an open-hole interval usually include an inverted shroud intended to reduce the amount of free gas entering the pump. Such installations would not function as a motor cooling device.
The large degree of production loss and the increased operating cost incurred by unplanned ESP shut-down and failure have been two of the major challenges faced by the asset teams of South Fuwaris (SF) and Humma (HUM) Fields in PNZ-Kuwait, in their efforts to maximize the uptime of low-volume high-GOR ESP-equipped open-hole producers. A customized shrouding system was needed to simultaneously resolve the issues of motor cooling and the reduction of the amount of free gas entering the pump. The dual functioning nature of a shrouding system composed of a conventional shroud combined with an inverted shroud was the main feature that had to be incorporated in the design of such system.
Through the continuous efforts of the South Fuwaris and Humma asset teams, a novel dual-shrouding system has recently been developed to fulfill the requirements of cooling of the motor and reduction of free gas entering the pump simultaneously. Multiple customized versions of this system have been installed in critical low-volume high-GOR open-hole producers since the 4th quarter of 2009.
Examination of historical operating conditions of ESP strings equipped with the new shrouding system showed a significant reduction in the number of ESP shut-downs due to underload, overload or high motor temperature trips, and a dramatic drop in the number of ESP failures caused by overheating of the motor.
This paper discusses the benefits of the newly-designed shrouding system and its built-in perforated tail pipe, specifically designed for low-volume high-GOR producers in South Fuwaris and Humma Fields, and actual results achieved from field implementation of this system.
The Interactive Plant Model, A New Approach to Facilities Integrity
Authors: Sharaf Omar 
Published: February 2011

Abstract
This paper presents a comprehensive guide to creating, viewing and editing a 3-D panoramic model of any facility. The model allows the user to easily interact with the different units within the facility by simply clicking on them. An average user who has never been to the facility could become familiar with the plant in a few clicks of a button. The model manages to incorporate operating envelopes, technical integrity reports, P&IDs, operating manuals, procedure guides, unit descriptions, daily reports and HSE specifics in a user friendly fashion. This allows newcomers and experts to communicate and share information easily while minimizing chances of error. Such a model could be installed and downloaded on a network to manage information, collect historic data, manage changes and follow up plant activities.
Wellhead Compression on Tight Gas Wells in the Long Run: A Follow-Up Case History on Seven Years of Success in Lobo
Authors: Harms L.K. 
Published: February 2011

Abstract
Many times lowering surface pressure results in production increases on tight gas wells but how does that increase hold up in the long run and what is the rest of the story on wells that originally did not show increases? A previous paper (SPE 90550) detailed results at the start of a long range program to install wellhead compression (WHC) in ConocoPhillips' Lobo Field in South Texas. Updated data showing the long term results over seven years on the original 21 wells are presented as well as results and lessons learned from over 40 additional installations. Based on these experiences, a general approach toward choosing candidates and operating wellhead compression on tight gas wells is proposed.
Improved Flaring Technology: High Pressure Air Assist System for Smokeless Flaring
Authors: Mashour Mazen , Smith Scot , Palfreeman Nigel , Seefeldt Greg 
Published: February 2011

Abstract
In order to meet increasingly strict environmental regulations and to promote cleaner energy at their facilities, many oil, gas, and petrochemical companies are seeking to upgrade existing flares to allow smokeless flaring of hydrocarbon gases. Poor public perception of existing smoking flares increases the difficulty of operations, so upgrading systems to smokeless operation minimizes the environmental impact and improves local acceptance in urban areas. The main areas of application for these flare upgrades are harsh environments located in Russia, Africa, Middle East, South America, and other countries with high oil production capabilities and programs. Many of these areas have utility flares located in facilities where a shortage of steam or water prevents conventional smokeless steam-injection systems from being added. A new technology is needed for these kinds of applications.
Acid Effect Life Cycle in Carbonate Reservoir, Field Case
Authors: Al-Marzouqi Mariam , Al-Farisi Omar , Amer Mohamed Mostafa , Serry Amr , Yammahi Fatmah 
Published: February 2011

Abstract
In one of the biggest carbonate reservoir in offshore Abu Dhabi that has been producing oil for more than 40 years, oil potential evaluation is affected by many uncertainties as evaluated via pulsed neutron technology across perforated intervals.
The Acid used to stimulate the wells after workovers affect the responses of the pulsed neutron logs. Efforts have been exerted to eliminate this effect. Observations from this field showed that the acid life cycle in the formation can be extracted by comparing and correlating several pulsed neutron sigma logs that are acquired over the years across the same perforated intervals.
It has been noticeable that one of the most influential parameters in removing or eliminating acid existance in reservoir rock is water production, otherwise acid effect on pulse neutron sigma log interpretation remains, resulting in calculating high water saturation across dry oil producing zones.
Understanding this acid effect life cycle helped understanding reservoir performance and reducing uncertainty of pulse neutron sigma interpretation. This paper is showing these observations in our field and is detailing acid effect modeling on pulsed neutron log responses.
Estimation of Fracture Properties for a Horizontal Well with Multiple Hydraulic Fractures in Gas Shale
Authors: Aboaba A. , Cheng Y. 
Published: February 2011

Abstract
Pressure transient well testing is an important tool for evaluating well performance and reservoir characteristics. However, conventional pressure transient test often becomes impractical to wells in shale gas reservoirs due to the nature of extremely tight shale formations.
This study presents a new method for estimating fracture properties for a horizontal well with multiple hydraulic fractures in shale gas reservoirs. The method analyzes commonly available production rate and pressure data to provide reliable estimates of both fracture half-length and formation permeability. The method first converts variable rate-pressure data into an equivalent constant-rate pressure drawdown test, and then pressure transient analysis techniques are applied for property estimates.
Our new approach is primarily based on analysis of linear flow dominated data for estimates of both matrix permeability and fracture half-length. It doesn’t require the existence of the elliptical flow or the appearance of the pseudo-radial flow for independent estimate of matrix permeability. This is very important because we can estimate the properties from early-time production data for horizontal shale gas wells. Synthetic cases are presented to validate the proposed method and demonstrate its applicability.
Conventionally Undrillable Open Fractured Reservoir, Successfully Drilled Using Managed Pressure Drilling Technology in Algeria
Authors: Hamoudi B. , Kartobi K. , Qutob H. , Arnone M. , Torres F. , Murray C. , Barakat N. 
Published: February 2011

Abstract
The Field was discovered in 1960 during the exploration phase, this field is located between the Hassi Messaoud field and Rhourd de Nouss Central Field in the Triassic Basin in Algeria. The field represents many challenges for conventional drilling due to the complexity of the geological structures, one of these is the Hamra Quartzites formation; a gas reservoir sandstone highly tectonically fractured. The drilling history of this formation shows events of total fluid losses leading to gas kicks due to the loss of hydrostatic head in the annulus.
A 6″ hole section in NZ-XX well was planned to be drilled under the Constant Bottom Hole Pressure (CBHP) technique, throughout the Gres de Ouargla and the Hamra Quartzites formations; bounding the drilling window by the estimated formation pressure as lower limit, and the fluid losses pressure (hydrostatic pressure of mud used in offset wells) for the upper limit, both estimations were done at the top of the reservoir. The drilling window for Managed Pressure Drilling-MPD was validated by determining the Bottom Hole Pressure where both, an influx from the formation and fluid losses occurred. These values were later used to establish the target Equivalent Circulating Density-ECD to drill the hole accordingly.
The ECD management was achieved by controlling both, the surface back pressure and the annular out-flow; monitored in real time. The Bottom Hole Circulating Pressure-BHCP changes recorded in a Pressure While Drilling-PWD tool, placed in the Bottom Hole Assembly-BHA.
As the drilling progressed, fluid losses were experienced and instantaneously controlled by reducing the ECD. Despite the lower and upper MPD window limits converged, drilling continued managing losses as no open operating range existed. As a contingency for this scenario, switching to the Flow Drilling technique (UBD) was proposed and planned, but due to environmental restrictions, flowing the well while drilling was not possible. The MPD operations in NZ-XX successfully achieved 191 meters of open hole; then TD was called due to a combination of increasing losses – gas influx conditions and increasing risk of total losses in the underlying Hamra faulted structure.
This paper describes in detail the successful MPD application which is considered a start he drilling technology to enhance Nezla field exploitation. Lessons learned and challenges encountered will also be discussed in this paper.