bluuebunny/crossref_metadata_2025 huggingface dataset:
The Effect of Oriented Perforations as a Sand-Control Method: A Field Case Study from the Varg Field, North Sea
Authors: Tronvoll Johan , Eek Arne , Larsen Idar , Sanfilippo Francesco
Published: December 2007

The Varg field located in the central North Sea started production during the fall of 1998. It is located in a complex compartmentalized structure with different pressure regimes. The reservoir quality is generally good exhibiting partly heterogeneous sands containing weak and soft layers and partly homogeneous high-permeable and weak sand bodies. The field stresses are complex due to a number of faults, and indications of stress field rotations in wells in the proximity of faults have been observed. Precise mapping of the stress field has not been possible. Well testing data showed evidence of sand production in one appraisal well, and sand production indications were seen in another well. A sand production risk analysis was conducted prior to completion of the wells, and the risk of sand production was judged substantial. Based on perforation stability computations, selective and oriented perforations were suggested as a method to minimize the sand production risk. A majority of the producers were completed using oriented perforations at 0-180 deg. phasing. Since then no serious sand production events have been reported to date even though reservoir depletion of more than 100 bar (1450 psi) has been experienced in most reservoir compartments. The paper describes the field history with respect to production rates, productivity and sand production, as well as the analysis methodology and input data acquisition. The potential of oriented perforations as a sand control method is discussed on the basis of the field case comparing theoretical computations with field data.
Influences of Ultrasonic Radiation on Asphaltene Behavior With and Without Solvent Effects
Authors: Shedid Shedid A. , Attallah Saad R.
Published: December 2007

Asphaltic crude oils have caused serious problems in the oil industry all over the world. The major objectives of this experimental study are to investigate the influences of ultrasonic radiation on the behavior of asphaltene in the UAE crude oil, with considerations of temperature and solvent concentration effects. To achieve the goals of the study, two sets of experiments were undertaken. In the first experimental set, many identical crude oil samples having initial asphaltene content of 1.76 wt. % were subjected to different time intervals of ultrasonic radiation. Viscosity of these oil samples was measured under different temperatures. In addition, microscopic images of the centrifuged oil samples and Differential Thermal Analysis (DTA) of extracted asphaltene clusters were carried-out. In the second set of experiments, asphaltic oil samples of different solvent (toluene) concentrations were subjected to different intervals of ultrasonic radiation and under different conditions of temperature. Again, variation of oil viscosity with temperature was measured.

The results showed that subjection of the crude oil to ultrasonic radiation decreases the size of asphaltene clusters. Consequently, this effect increases the suspension of asphaltene in the crude oil and reduces/prevents its tendency to precipitate at 10 minutes or more radiation time. Furthermore, the results indicated that the use of ultrasonic radiation with toluene solutions increases the solubility of asphaltene in the crude oil at 10 minutes or more ultrasonic radiation time, but with more reduction in oil viscosity than that one with non-solvated oil. The application of the obtained results of the study could have real impact on the future development of simulation models, prevention of asphaltene precipitation and elimination, or at least minimization of the expected problems of asphaltene deposition.
Assessment and Diagnosis of Inorganic Scaling Potential Using Near-Infrared Technology for Effective Treatment
Authors: Ohen Henry A. , Williams Lee E. , Lynn Jack D. , Ali Liaqat
Published: December 2007

Inorganic scaling is a predominant formation damage mechanism in most producing and injection wells worldwide. Scales are deposited from oilfield brines when there is a disturbance in thermodynamic and chemical equilibrium. The degree of super saturation caused by the disturbance in equilibrium can be increased to result in scaling by changes in fluid composition through adverse mixing and by changes in temperature and pressure.

Although a few cases have been reported of non-water producing oil wells that produced scales, typically oil field scaling accompanies water production. Scaling problems during well development and supplemental fluid injection are primarily due to mixing of two incompatible fluids, whereas production related scaling is typically controlled by pressure and temperature. Acid or any common solvent cannot easily remove some types of scales like barium sulfate (BaSO4), which readily incorporates radioactive radium in its structure. Therefore detection and prevention is critical wherever any precipitation or co-precipitation that includes BaSO4 may be taking place. As severity of scaling is controlled by temperature, pressure and composition, the key to the detection, prevention and effective treatment is a methodology to determine at what conditions in the reservoir or at what point in the well the scales are precipitated and deposited and also determine the type of scale. This is important because sometime scales can be forming at a point in the well bore without showing up at neither the surface or at the sand face.

Near infrared (NIR) technology has been extensively used in detecting the organic scales such as asphaltene deposits. To the best of our knowledge, this study presents the first extensive use of NIR technology to diagnose inorganic scaling problems.

This paper presents several examples where NIR technology has been used to detect the onset of inorganic scale as a function of pressure depletion at reservoir temperature for water from different fields. We also show how the NIR technology has been used to determine the effectiveness of various commercial inhibitors at reservoir conditions. We also present further screening of the inhibitors (selected based on the results of NIR tests) to determine their effective use in the field and the design of the inhibitor treatment for the producing wells.
Specific Fluid Requirements for Successful Coiled Tubing Fracturing Applications
Authors: Cawiezel Kay E. , Wheeler Richard S. , Vaughn David R.
Published: December 2007

The recent success of coiled tubing fracturing in shallow wells has increased interest in using coiled tubing for fracturing deeper and hotter wells. Industry efforts need to now focus on understanding what properties of a fracturing fluid are required to successfully carry proppant at high rates through the coiled tubing, fracports, perforations and into these deeper formations. The key performance requirements of a coiled tubing fracturing fluid for deeper wells are low friction pressure and adequate proppant-carrying capability after exposure to high shear zones and higher temperatures.

This paper summarizes the results of pilot and field scale testing that led to the development of an optimized coiled tubing fracturing fluid. Results show that polymer-based fracturing fluids can be controllably delayed to have low friction pressure through the curved coiled tubing unit and straight tubing. However, results also show that fluid stability can be significantly reduced when pumped through small diameter tubing followed by high shear zones such as fracports and then perforations. Results demonstrate that correct fluid choice and fluid optimization are required to meet proppant transport requirements. For coiled tubing fracturing to be successful, the fluid and treatment design recommendations should balance the friction pressure limitations with the fluid stability limitations.
Fracture Stimulation of the Morrow Formation with Crosslinked Methanol: A Case History
Authors: Malone Mark R. , Nelson Scott G. , Greenlees William M.
Published: December 2007

Proposal

In recent years several papers have been written on the merits of fracture stimulation with crosslinked methanol. While crosslinked methanol has been available to the industry since the late 1980's, only in recent years has it been successfully and routinely utilized in the continental United States. In areas such as the Permian Basin it was thought that the best application for crosslinked methanol would be in older wells, or in new wells drilled in under-pressured Morrow reservoirs. It was not until the case history wells in this study had been treated that the fluid was proven to be successful on new and relatively undamaged Morrow reservoirs.

This paper will discuss the fluid system with focus on recent refinements in fluid chemistry. Special attention will be given to standard procedures implemented to ensure the system is pumped safely. An overview of the reservoirs where crosslinked methanol has been applied successfully, along with treatment parameters will be discussed. Finally, a production study of the case history wells relative to offset Morrow producers will be reviewed.
Nondamaging Viscoelastic Surfactant-Based Fluids Used for Acid Fracturing Treatments in Veracruz Basin, Mexico
Authors: Artola Pedro , Alvarado Oscar , Huidobro Efrain , Salmorán Angel
Published: December 2007

For the last eight years acid fracturing stimulation has been performed in the Veracruz basin to increase gas production in naturally fractured carbonate formations. Several techniques have been proved to enhance the results of these jobs, including the diverting technique and the application of nondamaging viscoelastic fluids technology specifically a self- diverting viscoelastic based acid system and a polymer-free viscoelastic surfactant gel for fracture initiation and propagation.

This paper presents the results of successful acid fracturing treatments recently performed using nondamaging viscoelastic surfactant-based fluids to increase gas production from naturally fractured carbonate formations.

Most of the wells drilled and completed in the carbonate formations of cretaceous age in Veracruz basin do not flow naturally because of low matrix permeability and drilling/completion fluids damage. Therefore, acid fracturing treatments are necessary to produce these wells at economical rates.

The objective of these treatments is to increase gas production by creating a deeply etched fracture that will bypass the damaged zone and connect to the network of natural fractures and/or fissures. The etched fracture length affects well performance in low-permeability reservoirs; increased fracture length should result in greater production response. The use of nondamaging viscoelastic fluids is necessary to obtain longer effective etched fractures. Combining this with the properties of a viscoelastic diverting acid will significantly increase fracture conductivity as well as the effective stimulation of all perforated intervals.

The fluids were combined by using a pumping technique that consists of alternating stages of nonreactive fluids, reactive fluids and diverter fluid to reduce wormhole creation at the nearwellbore area and increase etched fracture length.

Four field cases are presented in this paper. In three, multiple intervals were treated, resulting in longer etched fractures as deduced from after-treatment production response and radioactive tracer logs. In the fourth case, not all the intervals were effectively stimulated because diversion was not used.
Acoustic Removal of Colloidal Particles From Berea Sandstone
Authors: Poesio Pietro , Ooms Gijs
Published: December 2007

During the production of oil from a reservoir, permeability decrease due to fouling particles in the near well-bore region leads to a significant decline in productivity. Several techniques (acid treatment, hydraulic fracturing) have been used to overcome this problem, but many drawbacks make them unattractive (they are expensive or environmental unfriendly, for instance). A relatively new technique has been proposed: the ultrasonic irradiation of the near well-bore region. This technique is not always successful and before applying it, a more fundamental investigation is needed. To date, only few experimental data are available and a more systematic investigation is required prior to using the techniques effectively. We focus our attention on removal of fine clay particles in Berea sandstone by high-frequency acoustic waves. We designed an experimental set-up where down-hole conditions (pressure of 180 bars and 80°C) are simulated and where we can control independently all the relevant parameters. Two acoustic horns are used: 20 kHz and 40 kHz, with a maximum power of 2 and 0.7 kW respectively. The influence of several parameters has been tested; an increase in temperature produces a better effect on the cleaning, since the particles structures become more instable as a consequence of the increase of electrical repulsion and, at the same time, the wave penetration increases. Pressure is noted to have no effect above the cavitation point: if the tool operate above 120 bars no effect of pressure is observed, on the contrary lower pressures induce cavitation and then most the acoustic energy is lost before reaching the core. The key parameter of an optimal use of the technique turned out to be the flow rate: as the flow rate decreases the cleaning effect increases: this effect can be explained by the fact that high flow rate keeps, more strongly, the fouling particles into the pore throats. The effect of the initial permeability is investigated together with the effect of the initial level of fouling. A study on the most effective use of a certain amount of energy is carried out. As conclusion, we now have a better understanding of the influence of the relevant parameters on the ultrasonic cleaning.
An Improved, One-Step Cleanup System for Removing Mud Damage in Horizontal Wells
Authors: Ali Syed , bte Ahmad Atikah , Rae Phil , Gilmore Todd
Published: December 2007

Many wells are damaged in the course of drilling and workover by the use of drilling muds, drill-in fluids, and kill-pills that contain, amongst other things, polymeric constituents. The latter may consist of a single polymer or may consist of mixtures of polymers in aqueous solution/suspension which are added for the purposes of viscosification, leak-off control, lubrication, etc. Typically, the polymers used include xanthans, starches, celluloses, guars, and derivatives of these main groups. In addition, most of these fluids contain some form of particulate to impart density and to improve fluid-loss control, commonly calcium carbonate.

It has been established that well productivity can be significantly impaired by the use of these mixtures, due to the persistence of residues. Their removal can result in substantial improvements in production. There are those who believe that such damage can be removed simply by applying sufficient drawdown but, generally, chemical methods using acids and/or oxidisers like sodium hypochlorite are used. Neither of these approaches is effective alone at removing all the damage caused by cake components. This often necessitates multistage soak treatments, with large volumes of treating fluid, in extended reach wells. Such procedures complicate the operation and cause additional expense due to the time involved.

This paper describes a novel chemical system, capable of removing all common mud polymers while, simultaneously, dissolving the calcium carbonate and accomplishing this in a single one-step treatment. These systems are safe and effective and can remove essentially 100 percent of all residues, restoring permeability to its original level.
Evaluation of a New Barite Dissolver: Lab Studies
Authors: Nasr-El-Din H. A. , Al-Mutairi S. H. , Al-Hajji H. H. , Lynn J. D.
Published: December 2007

Proposal

Barite is a common weighting agent used for oil well applications. It is commonly used to provide adequate weight to control downhole pressures in drilling slurries. Since it is used for control of pressure, it is a common source of formation damage, especially in deep, hot formations where drilling fluid weights exceed 17 ppg. Although alternatives do exist for barite, (e.g., formate drilling fluids) they are significantly more expensive, and not available on a rapid turnaround basis as in emergency situations required by well control operations. Once damage has occurred, remediation is a very difficult proposition. Barite is not soluble in typical oilfield inorganic acids used in stimulation. The most common methods of remediation are fracture stimulation and/or deep perforations. The use of these methods can remediate the problem, but at high cost. Also, since the well productivity cannot be evaluated prior to stimulation operations, a poor quality well cannot be identified until a significant investment has been made.

The most common chemicals currently in use to address this problem are "barite dissolvers". These agents are all strong metal ion chelators. Aminopolycarboxylic acids (e.g., EDTA) and similar reagents have been used with low success rates.1 Recently, hydroxylaminopolycarboxylic acids were introduced, but to the best of the author's knowledge was not extensively used in the field.2

This study investigates a new barite dissolver and compares its performance with other commercial dissolvers. The new material is a proprietary dissolver supplied in a liquid form. This study investigates the dissolving capacity, and evaluates the effectiveness of the dissolver by conducting coreflood tests. These tests were conducted using sandstone cores obtained from a deep gas well (300°F). The effectiveness of the dissolver was followed by measuring the concentration of barium in the core effluent. Unlike other barite dissolvers, the new chemical is shown to be very effective in restoring the permeability of damaged cores. The new chemical does not require long soaking times, and does not induce fines migration due to chemical means.
A New Effective Stimulation Treatment for Long Horizontal Wells Drilled in Carbonate Reservoirs
Authors: Nasr-El-Din Hisham , Al-Habib Nabil S. , Al-Mumen Adib A. , Jemmali Mohammed , Samuel Mathew
Published: December 2007

Effective matrix acidizing of horizontal and multi-lateral wells is a very difficult task. Unlike vertical wells, horizontal wells can extend several thousands feet in the formation. Reservoir heterogeneity and the length of the horizontal leg make acid placement and diversion a real challenge. In addition, the low drawdown encountered in horizontal wells results in longer times to lift the spent acid from the well.

To achieve better acid diversion in horizontal wells drilled in carbonate reservoirs, a viscoelastic surfactant-based self-diverting acid system was utilized. The components of this new system are HCl and a viscoelastic surfactant. The acid dissolves calcite and dolomite minerals and produces calcium and magnesium chlorides. The increase in pH forces the surfactant monomers to form rod-shape micelles. The produced chloride salts further stabilize these structures, especially at high temperatures. The rod shape micelles will significantly increase the viscosity of the acid, diverting the acid into tight un-stimulated zones.

More than forty-five horizontal wells with openhole completions were successfully stimulated in two offshore oil fields in Saudi Arabia using the new treatment system. There is a water cap 30 feet away from these openhole (OH) sections in one of the fields, and growth of any dominant wormhole into these sections could increase water production. The wells that used the new treating fluid produced an average of 1,600 barrels of oil per day more than conventionally treated wells, with no indication of water production. Field results (pre and post oil and water production rates and FWHP) demonstrate the effectiveness of the new system to matrix acidize long horizontal wells with openhole completions. The simplicity of the system makes it the fluid of choice, especially in offshore environments. The absence of metals in this system helps in minimizing sulfide precipitation in sour wells.
Decision and Risk Analysis Study of the Injection of Desalination By-products into Oil- and Gas-Producing Zones
Authors: Burnett David B. , Veil John A.
Published: December 2007

When reverse osmosis (RO) is used to desalinate brackish water feed streams, a small but significant amount of the brine is discharged as a "reject" stream from the RO unit. This brine contains concentrated dissolved salts and other materials. Disposing of this brine concentrate for traditional RO processes can represent a significant fraction of the cost of operating the unit to recover fresh water. Coincidently, in the oil and gas industry, high salinity brines are routinely injected into formations for pressure maintenance and secondary recovery by water flooding. If water from desalination operations could be injected into these oil- and gas-containing formations, the estimated cost savings could be as much as 30% of the cost of operating the desalination unit. This represents a significant cost savings for RO technology that would make fresh water available to communities in need of this valuable resource.

To provide a comprehensive assessment of the perceived benefits compared to the possible hazards of this practice, we use risk analysis theory to define this process in more detail. The potential for formation damage, reduced injectivity, produced water scaling, and environmental impact is evaluated through comparison with traditional waterflood compatibility studies. We also provide an analysis of how state and federal Underground Injection Control (UIC) rules may be used to regulate injection of RO reject brines. The risk analysis study goes beyond classical decision analysis theory to address the "triple bottom line" economic, environmental, and societal benefits afforded by the process and provides a roadmap to gather quantifiable information for regulators, businesses, and community leaders who might consider this technology.
OTTER North Sea Subsea Field Development: Sand Control Strategy and Implementation
Authors: Profinet J. , Petit G. , Goyalon D. , Horn M. , Furgier J-N. , Coudeville F.
Published: December 2007

The OTTER field is the first to use a 'dual ESP' completion in a subsea field, the project was developed by TOTAL and its partner's in the Brent sand reservoir, in the UK North Sea sector.

This development consists of three horizontal open hole oil producers and two cased hole water injectors, drilled from a combined drilling template and production manifold and tied-back to the EIDER host platform 21km away. Each oil producer can deliver up to 20,000 BOPD, the field has been on production since October 2002.

A risk of sand production during the life of the field was identified, therefore downhole sand control was deemed necessary.

Well longevity has a major impact on the global project economics. Achieving and maintaining sand free production through optimal completion design was therefore critical to the overall success of the development.

This paper describes the strategy adopted and the factors considered in the development of the sandface completion optimised for the field life. Decisions on the sand control technique decisions were made while drilling the well based on cuttings particle size analysis: too small would have lead to open hole gravel pack. By eosteering the horizontal drain to stay within the most competent a sand body it would be possible to use a Stand Alone Screen completion, which was considered as the best option (cost, risk, and efficiency). The operationnal experience gained and lessons learnt on the first well contributed to the design enhancements required for completion of the following horizontal wells.
Sand Management Solutions for High-Rate Gas Wells, Sawan Field, Pakistan
Authors: McPhee C. A. , Enzendorfer C. K.
Published: December 2007

Formation damage, sand production and a HP/HT sour gas environment are major challenges in the field development of the Sawan gas reservoir in Pakistan. Meeting individual well productivity targets (average of 80 MMscfd) requires minimal-restriction (large bore or monobore) completions, minimizing formation damage via under-balance perforation and maintaining sand production below tolerable limits.

The reservoir sands are extremely heterogeneous with many thin, weak layers. Sand control completion concepts are based either on internal gravel packs (IGP) or, if the weaker layers are less extensive, on selective perforation. To avoid having to kill the wells (which can lead to significant formation damage) the completions are run prior to perforating. This meant that the sand control decision for each development well had to be made in 3 to 4 days - between logging the well at TD and running the completion.

The key elements of this "real time" sand management strategy were: the application of Fuzzy Logic computing techniques to correlate wireline log responses with core measurements, which enabled a field-calibrated, continuous sand failure prediction tool throughout the reservoir intervals;coupled well performance and geomechanical models to evaluate if selective perforation could safeguard well deliverability yet ensure sand-free production, standardization of critical completion equipment and simplified nipple-less completion design which provided the necessary operational flexibility, lowered overall completion cost, and reduced the risk of equipment failure.under-balanced through-tubing perforation with coiled tubing to minimize formation damage.

This integrated completion and sand management strategy has delivered well production rates in excess of 100 MMscfd with sand production significantly below tolerable limits. It has also has created substantial cost savings and reduced completion failure risks compared to conventional cased-hole sand exclusion completions.
Predicting Critical Drawdown for the Onset of Sand Production
Authors: Yi X. , Valkó P. P. , Russell J. E.
Published: December 2007

Sanding onset prediction models are used to forecast the production condition, e.g. pressure drawdown or flow rate, at which sand production occurs. A sanding onset prediction model is critical for sand control decision-making in answering the questions whether or not sand control should be used, or when to use sand control. There are a variety of numerical and analytical sanding onset prediction models available in the literature. However most of those models either need one or another rock mechanics input parameter which is rarely available in field practice or demand extensive computations (e.g. Finite Element models) that is not practical in cases when quick sand control decision is needed. As a result, the usage of those models in field practice is limited.

In this paper, simple and easy-to-use analytical sanding onset prediction models are derived based on theory of poroelastoplasticity assuming shear failure or tensile stress induced sanding from open hole well or from the perforations of a cased well. To use those models, the only rock mechanics parameters needed are Biot's constant, Poisson's ratio, Uniaxial Compressive Strength (UCS), and in-situ stresses. With those data, a critical drawdown pressure for a well can be obtained for any given average reservoir pressure.

Using those models, published and field reported sanding problems are studied. Through this study, sanding mechanisms for those cases are explained and good agreement is reached between predicted and field measured critical drawdown pressure.
An Integrated Approach to Impact Assessment
Authors: Macklin Stephen , Hartog Jan J.
Published: December 2007

Impact Assessment is continuously developing both in process and in application. Increasingly society expects that business should make a broader contribution to it. This has translated in impact assessment to spending more effort on enhancing benefits as well as mitigating the negative impact of our activities. Society is also expecting more openness and transparency, with greater communication and engagement on issues throughout the impact assessment process.

New developments in impact assessment include increasing attention to social, health and biodiversity impacts, and integrating environmental, social and health aspects. Increasingly attention is being given to integrating impact assessment within the project/business processes and integrating the results of the impact assessment into project/business execution. Furthermore, impact assessments are being applied to an increasing range of projects, as well as to earlier phases of decision-making such as country entry. Also, Strategic Environmental Assessment is emerging as a new regulatory requirement in some areas of the world.

The paper will outline the recent developments within and key challenges faced by Shell EP, and the key features of its new integrated impact assessment approach. Of particular note will be how biodiversity and health are addressed in the impact assessment process.
ESIA - More than a Tick in the Box?
Authors: Finney Robert , Witchalls Ben , Davies Gareth , Rogers Liz
Published: December 2007

Integrated environmental and social assessment is increasingly becoming part of national regulatory approval processes, to estimate and manage the impacts of oilfield developments upon the natural and human environment. Even at pre-project stages, the Environmental and Social Impact Assessment (ESIA) can form part of the company decision-making for country entry. Effective integration of the ESIA process and findings into the engineering design process can deliver benefits in impact mitigation and environmental management across all stages of the development. The ESIA should not therefore be viewed simply as a regulatory "tick-in-the-box".

The international community is demanding increasingly rigorous environmental and social assessments of planned developments by international operators and reputation can be strongly influenced by the consistency and quality of the assessment process and the extent to which ESIA commitments are delivered. It is recognised by the International Association of Oil & Gas Producers (OGP) that sharing of experience through "lessons-learned" would provide a means to achieve consistency in delivery of high quality environmental and social impact management.

The OGP ESIA in Projects Taskforce has been formed to develop industry guidance, which will be applicable to development projects in any geographical area. This will facilitate the attainment of a consistently high standard by all operators, to align themselves with international expectations. The aim is both to add technical value and to facilitate interactions with stakeholders and third parties. Given the diversity of project specifics, company internal processes, local environmental sensitivities etc., the approach must offer a high degree of flexibility in its application. "Building-blocks" based on agreed "good practice" to be assembled as appropriate, are viewed to offer greater potential than a more rigid process. In addition to direct application to oil and gas developments, extrapolation to downstream projects is possible.
The Green and Red Roadmap to a Safety Culture Where "Nobody Gets Hurt"
Authors: Gillette Ken , Haaland Dag K. , Steinsvik Dagfinn , Jensen Kjell Edgar
Published: December 2007

This concept is based on a "no blame" reporting system and the understanding of two different types of barriers. These include the traditional barriers which are described in safety manuals and the non-physical barriers which are embedded in the attitudes of a person. (Figure 2) A good safety culture is created by sharing with our colleagues what are observed to be potentially dangerous acts or procedures.

Green and Red hazard reporting takes place during the work process. A Green report is written on everything that has a potential danger, including your own mistakes. This becomes the book of learning that can deliver an accident-free workplace. Red reports are delivered concerning incidents where something undesirable has occurred. This reporting system is meant to catch those hazards that slip through the traditional barriers like Formal Risk Assessments, Work Management Systems, Procedures, Safe Job Analyses, and Personal Planning & Behavioral Tools.

The road to an accident-free work place has its last barrier in you and me; our eyes, ears and commitment to care for each other's safety. This proactive reporting system depends on each person's ability to spot safety hazards, intervene and share the lessons learned.

This ability is enhanced through: Visualisation of the hazard traps set by Mr. Incident (A character created to personify the dangers we face at Work.)Commitment to a safety contract: "I am your safety and you are my safety.""Safe Communication Analyses (SCA) by confirming conversations and securing two way dialogs.Role modelling of contributions needed along the road to 0 accidents (using the feedback and intervention skills).Developing a "healthy fear" for the job through personal insight and understanding of the potentially devastating consequences of accidents not only for yourself, but also for your work mates, the families involved, and the company you work for.
Improving Energy Efficiency in E&P Operations
Authors: Edwards John
Published: December 2007

BP has been striving to minimise the greenhouse gas emissions from its operations for several years. Since most emissions come from the combustion of fuel in processing operations, improving energy efficiency is the key to better emissions performance. The paper describes the tools and processes that have been developed to improve energy management and shares lessons from practical experiences of performance improvement in new projects and existing E&P operations. In all cases, improving energy efficiency has delivered significant business benefits.
Health Impact Assessment in co-operation with health community leaders and stakeholders - Breaking new ground in Russia
Authors: Boelens Paul R. M. , DeBello Mark
Published: December 2007

An Health Impact Assessment (HIA) for the Sakhalin II, Phase 2 project was conducted by Sakhalin Energy Investment Company (SEIC), with the support and participation of the Sakhalin Island health community. The HIA addresses the impact on the health of the island population during the construction and operation phases of the Project. Sakhalin Energy's objective is to ensure the health of its workforce as well as promoting improvements in the health of the community. The HIA sought to predict the impact on health of the Project before implementation, so that any negative effects could be reduced or avoided and positive effects enhanced. The HIA focuses on non-occupational health issues - i.e. it does not address occupational exposures for the workforce such as exposure to noise. Occupational exposures are identified and assessed in the Health Risk Assessments (HRA's) for each location.
Understanding Safe and Unsafe Behaviours: A Scientific Approach
Authors: Flin Rhona
Published: December 2007

The proximal causes of a significant percentage of oil and gas industry accidents relate to human error and unsafe behaviour at the worksite. In order to maximize safe behaviours and reduce unsafe behaviours, supervisors and managers need to understand the factors influencing them before introducing behavioural safety interventions. This paper argues that the same level of scientific expertise should be applied to the diagnosis, design and evaluation of behavioural safety interventions as is devoted to engineering interventions.
A New, Improved JSA Process Gets Enthusiastic Approval from Field Personnel
Authors: Veley Carl , Ritchie Norman , Coats E. Alan , Disatell Joel
Published: December 2007

Many oilfield companies require field crews to systematically analyze safety aspects of their activities before starting to work. Commonly, this process is called a Job Safety Analysis, or JSA, but other labels are also used.

Recent developments in measuring safety performance have changed the JSA process by redefining its objective. This change is definitely for the better, and it is rapidly gaining acceptance throughout the Gulf of Mexico petroleum industry.

A survey of Gulf of Mexico offshore production facilities and drilling rigs showed that JSAs tend to be a tedious formality that crews comply with only because they are required to do so. For a typical jack-up drilling rig, adopting this new JSA process and standard can reduce total time spent in JSA meetings from approximately 30 man-hours per day to less than four man-hours per day. Not only does the new style of JSA provide significant time savings, but it is considerably more effective in reducing the likelihood of accidents, meets with enthusiastic approval of work crews, and provides a powerful tool for onsite management.
Management Visibility
Authors: Arias Daniel
Published: December 2007

Nowadays, companies performance is measured from different approaches, among them, through the areas of Health, Safety and Environment (HSE).

There are many examples illustrating that weak performance in some of these areas may result in great economic losses or, even worse, in business collapse.

Senior management must generate and increase prevention awareness that must be adopted as an integral part of business management. Therefore, it is essential to define how HSEMS expectations will be met.
Managing Health for Field Operations in Oil and Gas Activities
Authors: Martin Alison
Published: December 2007

This new set of OGP guidelines aims to help oil and gas companies achieve and maintain high standards of health management for everyone associated with field operations.

The guidelines supersede three previous OGP documents produced in the mid 1990s and are designed to complement national and international standards and regulatory requirements as well as individual corporate health guidelines.

The paper will give an outline of the document covering topics ranging from health impact assessment through medical evacuations to food and water hygiene standards.

It will highlight the practical guidance within each chapter and will discuss the relevance of the advice to the populations the document serves.
Application of ‘Life Cycle’ Concept for Asset Risk Management
Authors: Dreher L. G. , Jarman M. F.
Published: December 2007

Risks arise at all stages through the life cycle of a project. For the optimum outcome, risk management approaches need to be applied considering the entire duration of the project. This paper discusses the application of these approaches, and provides examples to illustrate the benefits available to operators who implement risk management throughout the entire life cycle of an asset.
Drug Testing in the Workplace: A Case for Mandatory Random Testing
Authors: Ajayi P A , Faleyimu B L , Babalola R O
Published: December 2007

Substance abuse has clearly become a concern of the workplace and the business community and remains a major safety and health hazard.

The associated socio-economic and health burden is staggering and on the increase. The response to this problem has been the implementation of comprehensive workplace substance abuse prevention programs which include written policies, employee education, employee assistance programs (EAP) and drug testing. Of these components of workplace substance abuse programs, drug testing is the most sensitive and most contentious.

Most employers drug test employees in safety sensitive and security sensitive positions. Other indications include random testing, pre-employment, for course, reasonable suspicion, post accident and post rehabilitation.

Several studies have shown that the most effective deterrent to drug and alcohol use is random testing. Yet is it the most sensitive and contentious of all the test indications. This paper reviews random drug and alcohol testing in the workplace and suggests strategies for its effective use.
North Caspian Project - Challenges and Successes
Authors: Sarybekova Lyazzat
Published: December 2007

Oil & gas projects operating under extremely challenging circumstances or in the world's most sensitive environments are not a rarity. There are many examples where industry has successfully addressed such issues as unfavourable reservoir properties, lack of infrastructure, limited access, cold or hot climate, demanding regulatory requirements and unsympathetic public. Over the recent years industry aggressively developed and improved technologies and techniques that allow companies to significantly minimise the environmental impact of their operations and, thus, carry out projects in many areas with sensitive, vitally important or highly protected ecosystems. However, there are not many projects where most of the above mentioned challenges are present all at once.

The development of Kashagan field in Kazakhstan sector of North Caspian Sea is one of the biggest and the most challenging development projects worldwide, uniqueness of which lies in the complexity and rarity of a blend of issues requiring consideration. It starts with the properties of the field such as geology, pressure, temperature, H2S content. Then there is a number of physical conditions within the area of operations such as shallow waters, sea level changes, extreme temperatures in winter and summer seasons, and ice. Shallow waters and wetlands of North Caspian support important number of bird and fish species, including rare and internationally protected, and Kazakhstan enforces high environmental standards to ensure adequate protection for the area.

Agip Kazakhstan North Caspian Operating Company (Agip KCO), an Eni company operating on behalf of six international co-venturers, has the luxury and opportunity to draw on experience and resources that its founders acquired internationally. This paper describes some engineering solutions and operating methods as well as other protection measures employed by the Company to ensure maximum safety of its operations to the environment. Successes and lessons from this project may prove to be valuable throughout a wide sector of industry.
Environmental Significance of Mercury in Drilling Discharges
Authors: Parker M. E. , Smith J. P.
Published: December 2007

Environmental studies of offshore drilling activities, conducted over a period of more than two decades, have shown that the mercury present at trace levels in drilling fluid barite has very limited bioavailability to marine organisms. However, media reports during 2002 about the presence of mercury in fish raised the level of interest in the potential for drilling discharges to contribute to mercury levels in fisheries resources.

The exploration and production industry responded to this interest by preparing a comprehensive review of the scientific literature on the fate and effects of mercury in the marine environment, updating information on the quantities of barite (the main source of the low levels of mercury in drilling wastes) discharged during drilling, and collecting new data on the potential for inorganic mercury in drilling discharges to be converted to methylmercury once discharged into a marine environment. The literature review indicated that the presence of low levels of inorganic mercury in drilling discharges poses minimal environmental risk. A review of data on discharge volumes showed that modern drilling technology has reduced the amount of barite used per well by 50 - 80%. New field data showed that marine sediments close to drill sites did not have higher methylmercury concentrations than did sediments from more distant sites. This indicated that there is low potential for the conversion of inorganic mercury in drilling discharges to the more readily bioavailable organic methylmercury form. The overall results of this effort support the conclusion that the low level of inorganic mercury in drilling discharges does not contribute to organic mercury levels in fish.

This paper provides a general review of mercury in the environment, its fate and effects, and identifies the most significant sources. Against this background, the relative contribution and behavior of inorganic mercury from drilling discharges is presented. Industry research efforts over the years evaluating the fate and effects of mercury in the environment are reviewed with an emphasis on studies of mercury concentrations in drill site sediments, the chemical forms of inorganic mercury in drilling fluid discharges, and recent studies of the potential for conversion of inorganic mercury in barite to the more bioavailable organic methylmercury form.
Degradation and Ecotoxicity of C14 Linear Alpha Olefin Drill Cuttings in the Laboratory and the Field
Authors: Visser S. , Lee B. , Fleece T. , Sparkes D.
Published: December 2007

Laboratory and field studies were conducted on C14 linear alpha olefin (LAO) mud drill cuttings. In the laboratory, LAO drill cuttings applied to a loam soil at a total extractable hydrocarbon (TEH) concentration of 4.8% (wt:wt) degraded by 92% to a TEH residual of 0.38% after 3 months. This residual was nontoxic to plants, earthworms, springtails and Microtox™ bacteria based on both acute and chronic toxicity bioassays. Earthworm growth and reproduction after 2 months exposure to soil with remediated LAO cuttings were greater than in the untreated soil. In the field, LAO cuttings were spread over a silty loam soil in southern Alberta at an inital concentration of 3.1% (wt:wt) during the fall. The following spring the field was tilled, fertilized and planted with barley. The LAO in the soil degraded by 68% to a 1% LAO level by harvest (11 months treatment), and was further reduced to 0.25% after 23 months of landfarming treatment. At 1% LAO, barley growth was not significantly reduced in the laboratory or the field. In contrast, 1% LAO significantly inhibited earthworm growth and reproduction, and killed the springtails. The Microtox™ bioassay revealed no toxicity in water extracts of the soil. Co-composting studies in northern British Columbia involved mixing LAO cuttings with wood fibre at a ratio of 1:3 and applying fertilizer. After 22 months treatment, the TEH at two separate sites had decreased by 95%, from initial concentrations of 8.1 and 15.2% to final concentrations of 0.4 and 0.6%, respectively. Results to date indicate that C14 LAO drill cuttings degrade readily under both laboratory and field conditions, and that both landfarming and co-composting are effective means for eliminating and detoxifying C14 LAOs.
Management of Change Applied to Well Engineering
Authors: Bourque J. G.
Published: December 2007

Whether voluntary or imposed, changes are an accepted fact on well construction projects. While risk management has progressively become an integral part of the well engineering process, management of change has yet to gain the same level of implementation, and is often neglected. This potentially introduces new risks that are not properly evaluated. The result is the opening of a breach in the protective shield that risk management creates around the project. This in turn can lead to incidents.

A review of well construction incidents worldwide shows that the root cause is often traced to mismanaging changing conditions and unplanned events. Therefore, it is imperative to complement risk management of the well engineering process with structured management of change.

This paper briefly reviews the well engineering process and how risk management is typically performed on drilling projects. It then describes management of change and proposes a simple procedure for implementation on well construction and intervention projects.

Finally, several case histories are presented, illustrating both good and poor examples of management of change. In one example, tubing was ejected from a well during a workover operation because of poor management of change. In another example, a surface blowout was avoided by properly managing changes in the geological prognosis. These and other case histories were chosen to emphasize that management of change is an essential component of any quality, health, safety, and environment (QHSE) management system.