bluuebunny/crossref_metadata_2025 huggingface dataset:
Use of Mud Microloss Analysis While Drilling to Improve the Formation Evaluation in Fractured Reservoir
Authors: Beda G. , Carugo C.
Published: December 2007

Massive or small losses of drilling mud, flowing from the wellbore into surrounding formations, can be considered as good indicator of the natural fractures permeability and can be successfully used to support and integrate other detection methodologies.

Most of the techniques currently used for natural fracture detection do not clearly differentiat e between fractures that allow fluid flow and those that do not. Image logs, for example, can accurately locate the presence of fractures but are unable to discriminate between open and closed fractures. The most commonly used techniques to detect the mud losses consist in monitoring the level of the mud pits with acoustic, floating sensors and/or using paddles set inside the flow line that measure the return mud flow rate with a small degree of accuracy.

In the last years these sensors have been partially replaced by the more accurate electromagnetic flowmeters. These tools are able to measure the mud flow rate with an accuracy of around +/− 15–20 litres/min.

The mud losses are now processed in time domain and no more in depth domain, permitting a better accuracy in the identification and location of the conductive (microlosses) events. Moreover, the analysis of the microloss shape can allow the identification of the event causing the losses (natural or induced fracture, matrix porosity etc.).

The main advantages of using mud losses as permeability indicators can be summarised as follows: Direct information about reservoir permeability properties on a large volume of rock,Only conductive fractures are detected,Possibility of distinguishing damaged plugged up conductive fracture from impermeable ones,Inexpensive techniqueApplication and interpretation while drilling.

Some case studies are presented in this paper, showing how the microloss monitoring and analysis can help and support the conventional Formation Evaluation in the detection and location of productive fractures.
A System Engineering Approach to Field Development
Authors: Robertson A. L. , Cunningham P. R. P. , Gayton P. W. , Castell M. K. , Menzies N. A.
Published: December 2007

A system engineering approach can enhance the prospects of field developments by removing the demarcation between technical disciplines. Considering the system as a whole from the reservoir through to final export over the field life can real-ise significant benefits and this paper will demonstrate how this approach has been successfully applied to one project in detail.

The traditional approach to fields is for a reservoir team to analyse the reservoir development scheme and de-velop production profiles. These profiles then form the basis of the facilities design. The facilities design is then carried out on this fixed basis of design. Economics are then applied us-ing the capital cost from the facilities design and the produc-tion profiles from the reservoir analysis. This approach can take considerable time and can have little interface communication.

An alternate approach is to condense the reservoir knowledge into a model that can be integrated into an overall system model which can then be run over the life of field. The model is intended to be simple and fit for purpose and as such, the ease of calculation allows many more outcomes to be considered.

These models can be developed further to include the full economic analysis as well. As the models are simple and computationally efficient, risk analysis can be applied to them such that all the key uncertainties can be analysed and risk profiles developed. This can be used to develop the facilities in such a way as to reduce the development risks. This ap-proach is quick and efficient with the end result being a much more robust system design.
Using Rotary Closed-Loop Drilling to Increase Operational Efficiency and Reduce Operational Risk
Authors: Johnstone John A. , Gruenhagen Hartmut
Published: December 2007

This paper reviews the operational experience gained of utilizing Rotary Closed - Loop Steerable (RCLS) drilling technology on development drilling projects in the UKCS for the period 1997 - 2000. Despite the general decline in drilling activity in this period, there was a significant increase in RCLS drilling activity. Sufficient operational experience has now been gained to a) fully evaluate the impact of the new technology on the drilling operation and to b) make a comparison of RCLS system performance against a conventional drilling operation.

The paper focuses on the following three key performance measures of the RCLS operation: Reliability of the Technology: A review is made of the RCLS system performance, where problems occurred at the introduction of the technology and what solutions were implemented to improve system reliability.Operational Performance: An assessment of the factors which influence the operational efficiency of the RCLS operation is presented and a comparison is made with the operational efficiency of a conventional drilling operation.Safety & Environmental Performance: The introduction of RCLS technology facilitates a safer working environment for drilling operations at the rig site. The positive impact that the technology has made to the drilling operation is reviewed here.

In reviewing past performance, the direct and indirect advantages of deploying RCLS are discussed in light of experience gained on a number of offshore UK North Sea assets including those projects managed by low cost operators or where field economics are marginal.
Case Study: First Intelligent Completion System Installed in the Gulf of Mexico
Authors: Jackson V. B. , Tips T. R.
Published: December 2007

To maintain profitability in the development of marginal fields, many new technologies and concepts have been exploited. One of the most promising technologies has been the "Intelligent Well Concept," which allows the operator to produce, monitor and control the production of hydrocarbons through remotely operated completion systems. These systems are developed with techniques that allow the well architecture to be reconfigured at will and real-time data to be acquired without any well intervention. This paper concerns a case history in the Gulf of Mexico in which an operator was able to justify completion of marginal wells based upon the cost savings generated from innovative technologies.

The completion methods chosen for this development were successful because of careful preplanning for all phases of the completion scenario and proved that close interaction among all suppliers and parties involved in the actual equipment purchasing, interface issues, and all operational strategies is critical for project success. These topics will be discussed in depth. Detailed test programs were implemented during the design and manufacturing processes to eliminate field failures. In this case, testing revealed system issues that ultimately led to the use of an alternative design.

Also shown is the importance of allowing the proper amount of time to adequately plan and test these systems for their specific applications in order to assure delivery of a design that can meet the functional requirements for that application. In this case, although the system design was changed, the original functional goals were met. Two wells in this field were completed in April and July 1999. An additional well may be completed in early 2000.
Hydraulic Fracture Stimulation in Changbei Tight Gas Reservoir - Challenges and Achievements
Authors: Wong Sau-Wai , Hii King-Kai
Published: December 2007

The Changbei tight gas reservoir has presented a number of challenges in successful application of fracture stimulation techniques. In an appraisal program, 4 wells have been fracture stimulated. Issues related to fracture containment and high fluid leak-off in coal layers above and below the sand reservoir have led to a number of design and operation challenges. The fractures placed have led to significant production improvements, up to a factor of 10 over pre-frac production. This paper gives an overview of the treatment operations, and without going into details of fracture design and execution, key aspects are outlined and their implications discussed.
Use of Well Flowrate-Pressure Data to Estimate Formation Drainage-Area Static Pressure
Authors: Medina P. Raul A.
Published: December 2007

A method has been developed to estimate the reservoir drainage-area static pressure (P¯) and the well skin factor (s) through the analysis of flow-after-flow tests. Previous analysis methods of these flowing tests required the indispensable prior knowledge of P¯ for their analyses. The present method obtain P¯and s values from the proposed graphic method Log(Pwf /J) vs. Log(Q) and the equations presented in the paper.

Two previous published data of flow-after-flow tests in oil wells were analyzed, obtaining an excellent prediction of the reported static pressure in the first one and a different but consistent value in the second.

The method developed here is an approach to obtain information about the well-reservoir system through the use of common Production Engineering tools, like well Inflow Performance Relationship models. This approach would contribute in a simple and economic way to the continuous surveillance and study of the reservoir pressure behavior by drainage-areas. The method is likewise applicable to gas reservoirs.
Liquid-Free CO2/Sand Stimulations: An Overlooked Technology - Production Update
Authors: Mazza R. L.
Published: December 2007

The U.S. Department of Energy (DOE) supported the demonstration of a unique liquid-free hydraulic stimulation technology (CO2/Sand) in the water sensitive Devonian Shale's of eastern Kentucky in 1993. The initial production results from four wells which were stimulated with two-stage CO2/Sand stimulations indicated a significant advantage over N2 gas and N2 foam stimulations. The nine-month production responses from a 15 well (30 stages) study group were presented in SPE paper #29191 "Analysis of Production Response to CO2/Sand Fracturing: A Case Study" and reported a measured production benefit of CO2/Sand stimulations over N2 gas and N2 foam of 1.9 and 4.9 respectively.

This updated review includes: the 5-year production from those wells, the addition of three more single-stage CO2/Sand stimulation treatments, and the elimination of the early-time "flush" production from the analysis. The production responses for 21 wells (37 stages) is comprised of: CO2/Sand - 7 wells (11 stages), N2 gas - 9 wells (17 stages), and N2 foam - 5 wells (9 stages) are presented.
Report on First SPE Industry — University R&D Conference
Authors: Blasingame T. A. , Green D. W. , Kansas U. , Kamal M. M. , Kazemi H.
Published: December 2007

The 2001 SPE R&D Conference was organized to address the critical issue of industry-university-government partnerships in education, technology development, and technology transfer. The Conference was very successful in the sense that representatives from both the industry and academia appeared strongly willing to continue working together, with the solidarity in purpose, to expedite timely development and delivery of technology needs.

Specifically, it was concluded that industry is looking for new technologies and innovations that reduce cost and improve profitability; therefore, it is looking for value in R&D. Furthermore, R&D funding is not a major issue because good ideas will be funded.
Development and Testing of an Expandable Sand Screen and Expansion Tool
Authors: Echols Ralph , Gano John , Shy Perry , Tuckness Cindy , Zhang Haoyue , Campo Don
Published: December 2007

Many traditional sand-control completion techniques have inherent weaknesses that can significantly affect borehole stabilization and completion costs. Also, gravel-pack operations can increase logistical requirements in horizontal and extended reach wellbores. Finally, stand-alone screen completions are subject to borehole collapse and screen-erosion during production. A new technology recently introduced to the oilfield — expandable-sand-screens — has focused on providing solutions for these problems.

This paper will review a new expandable sand screen and associated expansion tool that shows promise of solving some of the inherent problems discussed above. The innovative sand screen system allows the screen to be expanded toward the borehole ID. This principally increases the sand screen surface area, thus reducing pressure drop across the filter and increasing production rates. Secondly, expansion helps to stabilize the borehole to minimize the potential for sand production. The new screen eliminates the need for gravel packing operations in many wells and provides a larger production ID than is normally possible with traditional screens.

The discussion will review 1) the development of the technology required to expand perforated pipe plastically, 2) the tools and techniques employed, 3) the development of the screen, and 4) the testing results. The discussion will also include a review of the first field trial of the expandable sand screen system.
Is Spurt Loss a Reality During Frac/Packing in High Permeability Formations?
Authors: Gadiyar B. , Morales R. H. , Norman W. D. , Gupta A.
Published: December 2007

In general, laboratory leak-off tests, either static or dynamic, are used to estimate the spurt loss. Most of the spurt loss values reported in the literature are measurements which result from the injection of brine based gels in brine-saturated cores. When using brine-saturated cores, an important aspect, which is the relative permeability to hydrocarbons, is neglected. The presence of hydrocarbons and the relative permeability to hydrocarbon and brine can significantly affect spurt loss.

This paper discusses the impact of hydrocarbons on spurt loss in high permeability formations. Results of static and dynamic leak-off tests of frac/pack fluids in the presence of mobile oil saturation are presented. The main observation is that the spurt loss in hydrocarbon-saturated cores is significantly smaller than that observed in brine saturated cores. Another observation is that spurt loss decreases with increase of the hydrocarbon viscosity.
Frac Packing in Soft Formations: Low Efficiency Fluids Exacerbate Formation Damage
Authors: McElfresh Paul M. , Khodaverdian Mohamad F. , Baycroft Perry D.
Published: December 2007

Hydraulic fracturing injection experiments were performed in unconsolidated sand under stress to delineate the mechanisms controlling fracture propagation and to determine the effect of these mechanisms on potential formation damage. The tests included injection of cross-linked guar and visco-elastic surfactant into 3-Darcy sand samples subjected to different overburden stresses. The following observations were made:

The experimental data indicate that fracture propagation in unconsolidated sand is primarily a result of fluid invasion and shear failure in a process zone ahead of the fracture tip. The shear failure is caused by large tip stresses or by pore pressure increase within the process zone. Three different invasion/damage zones were observed, including the external filtercake, the gel-invaded zone (or the internal filtercake), and the filtrate-invaded zone. Sub-parallel "micro fracturing" and complex fracture geometry was encountered. The sub-parallel fractures may be initiated at the tip or at the fracture wall due to shear failure and is dependent on the fluid efficiency and the type of leakoff, i.e., wall building or viscous. Field consequences of micro fracturing during stimulation may include early screenout, short fracture length and extensive formation damage as the fracturing fluid invades the sheared interfaces. Typically, lower efficiency fluids were associated with increased net propagation pressure and higher density of micro fracturing.

These findings suggest that injection of low efficiency fluids in weak, poorly consolidated formations results in a different type of formation damage, namely creation of sub-parallel micro fractures enveloping the main propped fracture, that could severely undermine post-stimulation productivity.
HSE Information Management in Real Time
Authors: Pickles Simon , Valoz Jesus , DeVol Ed , Leon Ronald
Published: December 2007

Within individual companies and throughout industry as a whole, superior Health, Safety and Environmental (HSE) performance and information is demanded by a variety of stakeholders. Internally, both lagging and leading indicators are viewed critically for assessment of the business and development of plans to improve. The historical barrier to conducting these kinds of assessments has been the inability to collect the data in "real time," store it in a common format and database, and make the information available in a format that is useful to stakeholders. Local requirements and methods of gathering and tracking data make it very difficult to create regionally comparable statistics, much less provide a comprehensive global picture.

The significant advances in information systems technologies during the last few years has made it easier to meet the challenges of providing a comprehensive network for the collection, analysis and communication of HSE performance data in real time. Information about HSE performance from remote locations around the world can more easily be shared and lessons learned more quickly and effectively with these new technologies.

This paper focuses on the challenges associated with establishing processes and systems for collecting and tracking both leading and lagging HSE performance indicators, and describes the issues, challenges, and lessons learned from the implementation of these systems and processes at a large multinational company.
Health Risk Assessment in the Upstream Petroleum Industry
Authors: Jackson Rajesh , Zainuddin Azizin , Singh Jaswant , Samuel Shamini
Published: December 2007

Safety is a paramount concern on every offshore platform. Potential threats such as fire or explosion or catastrophic release of hazardous materials under pressure are constant reminders of safety hazards. Detailed and systematic industrial hygiene assessments, however, have not been conducted at many rigs. Potential exposures at an offshore platform include: components of gas and crude oil, process chemicals, cleaning compounds, paints, fibers and indoor air quality, among others. As industrial hygiene programs expand in Asia, the use of Qualitative Health Risk Assessments (Qualitative Industrial Hygiene Assessments (QIHA)) is becoming popular among employers. QIHA is a tool used to evaluate and prioritize the risk of exposure to chemical in the workplace and provides a summary of occupational exposure information for a defined work exposure group. The QIHA approach goes beyond routine observation-based occupational exposure assessments to systematically review the workplace hazards and evaluate the exposure risks.
Enhance Human Performance through Advanced Ergonomics in Computer Workplaces
Authors: Leitao Joao Andresen , Larsen Reidun
Published: December 2007

SEPNo experienced a few cases of Repetitive Strain Injury (RSI) in 1992 and has since 1993 been monitoring computer workload, health complaints and RSI cases in the Company.

Eight years follow-up period demonstrates: That our employees report an increasing amount of hours spent on computer work, andA concerning high number of health complaints related to this work.

This paper presents how we:

1 Mapped the key elements workload and health; Developed our philosophy on variation of working as background for good ergonomic design of computer workplaces;Established management guidelines for work organization, education and awareness;Introduced furniture specifications, andRan a project for refurbishment of our offices.

We present a follow-up evaluation of this project after 1 year.

Finally we discuss the need for focusing on methods for registration and follow-up of "complaints" and "alert" for the fact that modern ergonomical solutions are computer based.
An Ecological Model for Assessment of Effects on the Environment of Deep Drilling Projects
Authors: Peball Ulrich , Predl Franz A.
Published: December 2007

Many companies show a strong commitment to the environment and to the prevention of pollution in their policy statements. But reality shows that the introduction of most environmental programs fail because of limited knowledge about the actual situation within a company.

ISO14001 requires a company to establish procedures to identify and control the environmental aspects of its activities. The identification of significant impacts enables the company to define environmental objectives and targets.

The real knowledge of mass balances and material flows offers an unique possibility for cost savings by switch to less waste producing or energy demanding technologies.
Building a World-Class EHS Management System after Environmental Crisis
Authors: Varella Irani , Fonseca Rui , Espinosa Beatriz , Cantarino Anderson , Botelho Tatiana , Slocum Dean
Published: December 2007

Petrobras, one of the world's leading oil and gas producers, strives to also be a leader in environmental, health, and safety (EHS) performance. A series of accidents in 2000 and 2001 have prompted Petrobras to totally rethink and rebuild its EHS function and means of delivering EHS assurance. The results to date include bold changes, including a re-organization of the corporate EHS function, an EHS strategy and integration of objectives and EHS targets into its corporate strategy/business plan, and development of a series of target, world-class management programs and capital improvement projects. This paper highlights some of the advances to date and how they have been realized.
Implementation of Hazardous Materials Communication (HAZCOM) Program in A Petroleum Company Facilities
Authors: Al-Safwani M. A. , Ayalp Ahmet
Published: December 2007

Scope:

This paper introduces Hazardous Materials Communication Program (HAZCOM) program that was introduced to the oil company management to develop hazardous materials communications in 1999. The Hazardous Materials Communication Program is a comprehensive system for communication of the hazards to employees by providing information, concepts, and training program for employees on the safe handling and use of hazardous substances throughout in an industrial work environment. The HAZCOM program is one of the fundamental elements of the occupational health and safety practices and procedures in today's industrial work environment. The program elements are: Chemical risk assessment (CRA).Training of all employees.HAZCOM in-house labeling for all chemical containers.Development of Chemical Hazard Bulletins (CHBs).Field audit.

Methods:

HAZCOM Program implementation was introduced at company major facilities including five refineries, nine gas plants and one oil producing plant. Designated project team for each facility performed a chemical risk assessment including (1) identification of hazardous materials and a complete inventory, (2) a risk assessment, (3) chemical storage conditions and compatibility, (4) methods of transfer, handling and unloading, (5) hazard control measures, and (6) use and maintenance of personal protective equipment. Conclusions and recommendations were made allowing potential problems to be prevented. The remaining elements of HAZCOM Program were also implemented by the project team who is responsible for each facility as per implementation plan. The HAZCOM Program implementation started in 1999 and completed at fifteen facilities by end of 2001. The program implementation for the remaining major facilities is in progress during the year of 2002.

Results & Conclusion:

The potential problems identified by the chemical risk assessment are to be addressed within the guidelines of three industrial hygiene programs: (1) a hazardous materials communication program, (2) a comprehensive occupational health hazard assessment program, and (3) a chemical emergency response preparedness program. These three programs make a comprehensive Hazardous Materials Protection Program encompassing an effective strategy to control workplace hazards, prevent accidents, and protect the worker health and environment.

The HAZCOM Program including chemical risk assessment establishes potential chemical risk to employees and facilities for a new plant process or the status of chemical risk at existing facilities. Properly designed and applied programs targeting these hazards can effectively control hazards and reduce the risk to employees and the work environment.

Areas of Interest: Health and the Working Environment:

45-Chemicals and Other Workplace hazards, 51-Industrial Hygiene, 48- Exposure Assessment
Bioremediation Study of Olefins, Mineral Oils, Iso-Paraffin Fluids and Diesel Oils Used for Land-based Drilling
Authors: Visser S. , Lee B. , Hall J. , Krieger D.
Published: December 2007

Increasing concerns over health and safety, as well as environmental impacts of diesel oil-based muds in land-based drilling applications, has prompted a search for safer drilling mud base fluids. There are two challenges. First, the drilling fluid must satisfy technical requirements. Second, it must reduce environmental health and safety risks. This paper summarizes research aimed at finding a synthetic base fluid that satisfies both requirements. Laboratory studies evaluated the degradability of diesel and synthetic base fluids, and the toxicities of the same fluids to a range of terrestrial flora and fauna. More specifically, biodegradation, seed germination and root elongation of two plant types, earthworm survival, and response of bioluminescent bacteria (Microtox™) were determined in a typical landfarm receiving soil containing the test fluids. Olefins demonstrated the fastest biodegradation and lowest toxicity after bioremediation, whilst iso-paraffin fluids and mineral oil degraded less readily and developed extreme toxicity during the three-month bioremediation period. Although 71% of the diesel oil disappeared through volatilization and biodegradation, it remained extremely toxic after bioremediation.
Reducing Leaks Offshore - A U.K. Regulatory Initiative
Authors: Pratt Derek B
Published: December 2007

In April 2000 the UK's Health and Safety Executive launched two initiatives, aimed at reducing the number of hydrocarbon leaks from offshore installations on the UK Continental Shelf. It was recognised that despite the progress made by the industry in improving safety in recent years, a plateau had been reached in what was previously a declining number of hydrocarbon releases.

The two initiatives were: inspection by HSE of all permanently-manned production installations on the UKCS, looking in detail at ten aspects of process integrity management, andinvestigation by HSE of all hydrocarbon releases occurring offshore within a 12-month period, to identify trends and root causes.

Both projects have had good support and co-operation from operating companies, many of whom have developed internal leak-reduction programmes which parallel the HSE work. HSE challenged the industry to reduce the number of "major" and "significant" releases by 50% by 31 March 2004, and itself pledged to devote a large proportion of it's inspection resources to this aim.

The inspection results so far show that a significant mismatch exists between what onshore management believe is the status of existing systems and procedures, and what actually happens offshore. Good policies and work methods are often not implemented properly. A particular problem is measuring performance - management often do not know how well their staff are doing. Likewise auditing is not being effectively used to identify weak areas, and communication of good practice and new standards is patchy.

The 2000–2001 release figures show "major" releases down 33% and "significant" releases down 8% - an encouraging start. Nearly half of all releases were from holes in the containment envelope, and nearly half occurred outside normal production operations. The main immediate causes were degradation of material properties and fatigue/vibration. The principal underlying causes were design deficiencies and inadequate condition monitoring.
Remediation of Sungai Bera Holding Basin, Brunei
Authors: Tandon Ashok , Ibrahim Pg. A. Hjh Masnah PAH , Morehouse Daniel , Seymour Mike
Published: December 2007

This paper presents the strategy adopted and execution of a project to remediate the Sungai Bera Holding Basin (SBHB). The site is located at Seria, Brunei Darussalam, and is situated on the west bank of the river Sungai Bera, adjacent to the South China Sea. The SBHB consisted of three unlined shallow holding basins, covering an area of approximately six hectares, and containing approximately 95,000 cubic metres of oily sludges and petroleum contaminated soils.

Remediation employs Low Temperature Thermal Desorption (LTTD) technology for treatment of the waste and recovery of the oil for recycling. The project is being undertaken by a Bruneian and Canadian joint venture company, and is due for completion by the end of 2002.

The tribulations and lessons learned from managing a remediation project of this scale from inception to completion are shared. The project represents the first major environmental remediation of this scale in Brunei, a small country without clearly defined environmental legislation. This paper discusses the project experiences with: Project execution strategy;Determining remedial objectives and the most appropriate clean-up standards;Establishing fit-for-purpose treatment technologies and methods;Characterising the basin contents, volumes and extent of contamination;Ensuring full alignment of all stakeholders expectations:Developing a robust QA/QC scheme, including external verification;Developing and implementing HSE plans;Local capacity building and sustainable development.

The results from this successful project are shared with the intention to assist other companies operating in SE Asia to develop strategies aimed at successful implementation of remediation projects.
Sustainable Technology – E&P Steps up to the Challenge
Authors: Waterfall Kevin
Published: December 2007

Sustainable development is about ensuring a better quality of life for all. This means a fundamental balancing of our economic, environmental and social responsibility. The paper explores why this is important to Shell and how technologies in E&P demonstrate our commitment to contribute to sustainable development, particularly in their contribution to: ■Efficiency improvement■Reduced footprint■Emission reduction

The paper addresses the fundamentals of technologies for the reduction of emissions and discharges, as well as those that improve reservoir recovery, improved economics, well performance and surface operations techniques and methodologies. These are illustrated by examples selected from around the world, both onshore and offshore.

Technology examples assessed include Virtual Reality, 4D seismic, Smart Wells and Expandable tubulars from downhole as well as surface facilities technologies, like ‘Twister" and new technologies such as fuel cells and the Hydrogen Economy. Implementation through "Gamechanger" and Realise the Limit methodologies are addressed, as is project risk management using Value Assurance Reviews from a Sustainable Development perspective, utilising the concepts of total risk management.

Remediation is also illustrated with some specific examples of how this is applied and due relevance is given to the social dimension of Sustainable Development.

Contributing to Sustainable Development means a fundamental commitment to balancing our economic, environmental and social responsibility and this paper demonstrates how E&P technology plays a significant role in contributing to the sustainable future.
Culture and HSE Management
Authors: Berg Sigurd K.
Published: December 2007

In petroleum related businesses the HSE management philosophies in the United Kingdom and Norway are in principle the same. In spite of this, there are indications that there are big differences in how the HSE management is performed between these countries.

Two offshore fabrication yards in UK and two similar yards and one offshore installation site in Norway have been compared. The statistics in this work are too small to generalise for the respective nations, but they do show a pattern that is worthy of concern.

Two projects were used as the basis of the comparison; both projects were both partly carried out in UK and Norway. The end product was located in the Norwegian sector of the North Sea.

The issues reviewed in this study include the following: ■UK and Norwegian legislation■HSE programs and policies developed by the client and the construction yard■Interaction between management groups and foremen versus the blue-collar workers■Behaviour, attitudes and group dynamics.

Even though the Statutory requirements and policies in both countries were more or less equal, the performance, attitude and behaviour related to HSE matters showed differences between UK sites and Norwegian sites.

The UK management teams were more aimed on statistics and the formal way of complying with the requirements than the Norwegian management teams.

The Norwegian foremen showed a mutual understanding of group dynamics related to the HSE goals and strategies. The UK foremen understood their personal responsibilities but not as a group. Their interpretation of the HSE policy sET a limit for the blue-collar workers commitment to safety.

The UK workers were aware of their own responsibility and the consequences if they did not comply with the requirements, but there was little group understanding for the same requirements. They had a strong invisible culture that governed their attitude and behaviour

The Norwegian blue-collar workers were also aware of their responsibility; they had good group relations, but that was related to the trade union understanding of HSE requirements, rights and demand.

The interaction between industrial culture, employment, organisation and the trade unions seems to be an important factor in the outcome of good HSE management and HSE control.
Study on the Main Environmental Pollutants in Produced Water Discharged from Petroleum Exploration and Production Activities at White Tiger and Dragon Fields
Authors: Huynh Nguyen Duc , Thuy Bui Thi Thu , Diem Bui Hong
Published: December 2007

Petroleum production and wastewater (produced water and industrial water) treatment on White Tiger and Dragon field

Field location

White Tiger and Dragon Fields are located in Block 9 of Vietnam Southern Sea, about 120km far from Vung Tau.

White Tiger Field has been produced from 1986, more than 100 wells have been drilled with production output of 20,000 tons/day.

Dragon Field was discovered in 1993 and has been produced from 1994.
The Population, Energy and Environment Program – Progress achieved in a Tripartite Dialogue in the Amazon Basin
Authors: Alba E. Mayorga , Santiago M. A. , Potes V.
Published: December 2007

The Program "Población, Energía y Ambiente" (PEA) is a response from the countries sharing the Amazon to the challenge of developing an oil industry compatible with the objectives of sustainable development. It is a joint initiative by OLADE – The Latin American Energy Organization- and the World Bank, aiming at supporting governments, industry and indigenous peoples in their dialogue for developing common criteria to improve the handling of environmental and social impact of oil operations.

At the origin, governments appointed high level official – National Coordinators (NC)- who comparing their difficulties in dealing with the social impact of oil operations agreed on the need of a long-term action plan, involving the key stakeholders from industry and indigenous peoples organizations. The PEA has hosted three meetings gathering the NC, company representatives, ARPEL – the regional industry association-, indigenous peoples organizations and COICA – the coordinating organization of the Amazon indigenous federations. As a result, the PEA has generated a tripartite dialogue that is paving the way for joint activities: National dialogues to open communications among key stakeholders inside countries,Development of an information network,Preparation of Reference Documents to harmonize industry regulations, andA training program to improve social and environmental standards and existing dialogue.

Complementarily, the PEA include other efforts, such as loans to governments wishing to engage in consultations prior to licensing blocks and a study comparing the distribution mechanism of oil rents focusing on the shares received by oil provinces and indigenous peoples affected by the industry.

The PEA Program is facilitating constructive tripartite dialogues – at national and regional level- and thus is increasingly becoming a platform for the identification and dissemination of Best Practices in dealing with the social impact. The proposed paper will present the background, progress achieved and challenges of this unique Program.
Implementation of Environmental Performance Evaluation and Its Challenges in an E&P Company
Authors: Lee Tzee Wan , Yusof M Radzuan b
Published: December 2007

PCSB adopts the EPE approach to environmental management as part of the continuous improvement process practiced under the company's Health, Safety & Environment Management System (HSEMS). EPE is a useful internal management tool which focuses on key issues. The process is easily implementable, especially when the HSEMS is already established. EPE enables the company to reduce environmental impact due to its operations in specific and measurable manner. The most challenging task in implementating EPE is identifying the right indicators. Identification of the right indicators will provide environmental data which the management can monitor and act on easily without requiring significant resources and unnecessary work on the part of the company staff.
Environmental Sensitivity Map (scale 1/250,000) for the Area from Ke Ga Cape to Ca Mau Cape Used for Oil Spill Response
Authors: Huynh Nguyen Duc , Manh Dao Duy , Thanh Tran Thi Xuan
Published: December 2007

In parallel with the great economic value created by oil and gas industry, the environmental protection in oil and gas activities including prevention and response of emergency situation - a cause of environmental pollution at high level, is also attached a special attention. In Vietnam, most of oil and gas exploration and production activities concentrate in the Southeast sea, where marine transportation is very active. Consequently, in this area, the risk of oil spill is particularly high. In order to respond with oil spill immediately and effectively, the establishment of an environmental sensitivity map for the areas that may be impacted is very necessary. This map will constitute basics to select priority areas for response and suitable response measures.
Explosives Safety: Safety Strategies for Operating Electroexplosive Devices in a Radio-Frequency Environment
Authors: Dickes Raymond
Published: December 2007

Transmitters operating in the radio-frequency (RF) spectrum create the potential for accidental detonation of electroexplosive devices (EEDs). This risk is magnified with the widespread use of EEDs in oil and gas-well perforating services, the potential for an EED to be ballistically connected to other explosives, and the proliferation of radio transmitters.

To prevent accidental detonations while using an EED in such an environment, one or more safety strategies are necessary. At least three different strategies—radio silence, site risk analysis, and RF-immune EED—have been used over the past 50 years. All three, when properly implemented, are successful in improving safety during EED use, but each strategy has the potential for disaster when not fully implemented.

This paper reviews the RF environment and the potential for accidental detonation of an EED caused by RF energy. It describes the problems and risks associated with the strategies of radio silence, site risk analysis, and RF-immune EEDs, and explains how the key elements of each strategy address these issues.
Oil and Gas Processing Facilities for New Field Developments in the Gulf of Campeche (México)
Authors: Nieto Jorge , Reyes Antonio , Verdejo Jorge
Published: December 2007

The new fields under development are situated in the Gulf of Campeche (Mexico) approximately 77 kms from Maritime Terminal of Dos Bocas, in water depths ranging from 0 to 40 mts, the main objective of these projects is to increase the gas production in the fields operated by PEMEX-Exploration & Production (PEP). It is proposed to perform processing the produced hydrocarbons mixture on an offshore platform to obtain transportable oil and gas streams, which are injected into separate pipelines. The processing scheme developed includes multistage separation and gas compression. The analysis of the processing scheme shows that the separated gas produced is rich in liquefiable components; therefore it must undergo condensate recovery. Cooling the gas to condense liquids carries out condensate removal. Gas cooling is performed by a refrigeration plant, which uses the propane as working fluid. Condensate produced is injected into the oil pipeline. Crude oil stabilization is performed onshore. The proposed system has several advantages over those that have been traditionally used in the installations operated by PEP. The production scheme proposed maximizes oil production and decreases compressor power requirements. Simultaneously, problems such as undesirable flow pattern in pipelines (slug and plug flow) and the presence of corrosive fluids (sour wet fluids) in pipelines are solved in the production scheme developed in the present paper.
A New Comprehensive, Mechanistic Model for Underbalanced Drilling Improves Wellbore Pressure Predictions
Authors: Pérez-Téllez C. , Smith J. R. , Edwards J. K.
Published: December 2007

It is generally accepted that the success of underbalanced drilling (UBD) operations is dependent on maintaining the wellbore pressure between boundaries determined by the formation pressure, wellbore stability, and the flow capacity of the surface equipment. Therefore, the ability to accurately predict wellbore pressure is critically important for both designing the UBD operation and predicting the effect of changes in the actual operation. Most of the pressure prediction approaches used in current practice for UBD are based on empirical correlations, which frequently fail to accurately predict the wellbore pressure. Consequently, the current trend is toward increasing use of prediction methods based on phenomenological or mechanistic models.

This paper presents an improved, comprehensive, mechanistic model for pressure predictions throughout a well during UBD operations. The comprehensive model is composed of a set of state-of-the-art mechanistic steady-state models for predicting flow patterns and calculating pressure and two-phase flow parameters in bubble, dispersed bubble, and slug flow. In contrast to other mechanistic methods developed for UBD operations, the present model takes into account the entire flowpath including downward two-phase flow through the drill string, two-phase flow through the bit nozzles, and upward two-phase flow through the annulus. Additionally, more rigorous, analytical modifications to the previous mechanistic models for UBD give improved wellbore pressure predictions for steady state flow conditions. The results of using the new, comprehensive model were validated against two real wellbore configurations with different flow areas. Field data from a Mexican well, drilled with the simultaneous injection of nitrogen and a non-Newtonian fluid and full-scale experimental data from the literature validate the improved model predictions. Additionally, a comparison of the model results against two commercial UBD simulators, which rely on empirical correlations, confirm the expectation that mechanistic models perform better in predicting two phase flow parameters in UBD operations.
A Drilling Contractor's View of Underbalanced Drilling
Authors: Murphy R. D. , Thompson P. B.
Published: December 2007

This paper is not a technical discussion of under balanced drilling (UBD). Nor is it a filled with "tricks of the trade" advocating a better technical means of drilling wells using UBD. It is a discussion about the best method, from one drilling contractor's view, to execute a safe and productive UBD project. There is no magic formula, no exotic management technique and no revolutionary equipment design that will guarantee success. Rather this is a frank discussion, without references, about the "mindset" that an operator and drilling contractor has when approaching a UBD project. The authors have worked as an operator and a drilling contractor on a variety of successful and unsuccessful (some disastrous) UBD projects. The goal of this discussion is to help the operator and the drilling contractor better understand the strengths, weaknesses, needs, concerns and goals of each other to better deliver a successful UBD project.
How the Bit Profile and Gages Affect the Well Trajectory
Authors: Menand S. , Sellami H. , Simon C. , Besson A. , Da Silva N.
Published: December 2007

The importance of wellbore deviation is well recognized by the drilling industry. An analysis of the directional behaviour of a drilling system must include the directional characteristics of the drilling bit. A comprehensive analysis of the directional behaviour of PDC bits is presented in this paper, including the effect of bit profile, gage cutters and gage length. Numerical simulations as well as laboratory tests have been carried out in order to better understand the mechanisms of PDC bits deviation and to evaluate the most important parameters affecting the directional behaviour of PDC Bits.

The analysis of the directional behaviour of PDC bits presented in this paper shows that each part of the PDC bit (bit profile, active and passive gages) plays a major role on the walking tendency and steerability of the bit. A quantitative evaluation of the contribution of these factors on the well trajectory (inclination and azimuth) is given.

A full-scale directional drilling bench was built to measure, for the first time, the walking tendency and the steerability of PDC bits. The results obtained demonstrate that the bit profile, the gage cutters and the gage length have a significant effect on the walking tendency and on the steerability of the PDC bits. A 3D theoretical rock-bit interaction model was developed to reproduce the drilling tests results.
Evaluation of Solids Carrying Capacity in Aerated Fluid Drilling: Real Scale Tests and Modeling
Authors: Martins A. L. , Lourenço A. M. F. , Andrade P. H. , Silva V. , Silva P. R. C. , Nakagawa E. Y.
Published: December 2007

This paper summarizes the results of two sets of experimental tests performed at PETROBRAS real scale test facility aiming the evaluation of solids return times in aerated fluid drilling. The effect of the following parameters was studied: liquid and gas injection rates, particle diameter and depth. Results indicate that the gas has a major effect in accelerating the liquid phase, which would be responsible for carrying the particles to the surface. The concept of effective liquid velocity coupled with an adequate procedure for particle sedimentation velocity calculation reproduced the experimental results adequately.