bluuebunny/crossref_metadata_2025 huggingface dataset:
A Sinusoidal Pressure Response Method for Determining the Properties of a Porous Medium and Its In-Situ Fluid
Authors: Bennion D.W. , Goss M.J.
Published: December 2007

Solutions to the equations describing flow in porous media under sinusoidal pressure conditions are available in the pressure conditions are available in the literature. Very little use has been made of this theory and the experimental applications reported have dealt with gases and no flow through the media.

Frequency response data from sinusoidal pressure experiments using liquids can be pressure experiments using liquids can be used to characterize the porous media and fluid properties. The lack of this type of data is probably due to the difficulty of generating the sinusoidal disturbances having sufficient frequency range and amplitude.

Measurements were made using a synthetic oil in an unconsolidated medium. Equipment was designed to generate pressure sine wave whose upper frequency limit was in excess of 1,000 rad./sec. The core was equipped with high speed pressure transducers at various positions along the medium which measured the positions along the medium which measured the pressure response at a known flow rate. pressure response at a known flow rate. The experiments were designed to study the effect of pressure amplitude and frequency on the response of the system. Comparison of the theory and these experiments indicates that there are definite frequency limits which may be used if the equations are to adequately describe the data. As the frequency and or permeability increases, the inertial terms become important.

This study shows that practical use can be made of existing theory to increase our ability to describe the flow of fluids in porous media.

Introduction

The measurement of pressure transient responses is one of the few methods available for the reservoir to communicate its rock and fluid properties to an observer.

Frequency response methods have been used by several investigators to determine rock and fluid properties. Experimental studies have been reported which used sinusoidal pressure inputs in gas filled porous systems with storage pores. Other porous systems with storage pores. Other investigators have used pluse testing methods to determine reservoir properties.

Several methods have been proposed for describing the behavior of pressure transients in porous media.
Real-time Analysis of Dynamic Data Acquired During Gelant Placement for Water Control
Authors: Shah P. C.
Published: December 2007

A new technique is developed for real-time monitoring of the gelant placement through interpretation of the injection rate and pressure history in a high-permeability water producing layer of a petroleum reservoir. The method makes the same assumptions as those for Hall plot analysis of the longer-term polymer injection, i.e., steady-state, radial, two-fluid, Darcy flow in the treatment layer. A piston-like displacement of the reservoir fluid by the gelant is assumed.

The derivation of the mathematical model underlying the technique is presented that leads to introduction of a parameter group named Differential Impedance to Flow (DIF). DIF is defined as the difference of the two fluid relative impedances (viscosity divided by relative permeability of the fluid, reciprocal of the well-known relative fluid mobility) divided by the permeability-thickness of the treatment layer. It is robustly estimated in real time from the slope of the straight line fitted over a fixed-width time window containing the most recent data in a specialized plot This is the plot of the derivative of the classical Hall plot versus the log of injected fluid volume. The estimation of DIF in this manner requires remarkably little information about the treatment zone formation or the reservoir fluids. DIF monitoring may lead to real-time conclusions about changes in the rheology of the gelant, the onset of gelation, the effect on the reservoir permeability due to gel adsorption, or encounter with reservoir heterogeneities such as change in layer thickness or permeability with radial distance from the treatment well.

Illustrative examples with synthetic data from one and two-layer reservoir models are presented that show the evolution of real-time estimates of DIF as the injection of a low viscosity (3 cp) gelant proceeds. In both situations, the correct value of DIF is estimated within a fraction of an hour of the start of injection and the value remains essentially unchanged when the injection rate is halved.

An example with field data is also presented, in which a medium viscosity (100 cp) gelant was injected into a high-permeability gas-producing zone in a sandstone oil reservoir. It illustrates the variability of apparent DIF values and the difficulties that may be encountered in interpretation of real injection data.
Techniques for Multibranch Well Trajectory Design in the Context of a Three-Dimensional Reservoir Model
Authors: Ehlig-Economides C. A. , Mowat G. R. , Corbett C.
Published: December 2007

Mullibranch wells offer a means to contact more reservoir per wellhead or platform slot. Optimal well plans must begin with a concept of the trajectories of the lateral branches within the productive reservoir zones These can be vertical, inclined or horizontal, as can the main trunk of the well. This paper provides criteria for deciding the lateral branch trajectories depending on reservoir properties, rock stress regime and the geometries of the productive reservoir units. Because production from several lateral wells can be commingled in a common main trunk, this may permit more holes to be drilled in the reservoir than would have been feasible with conventional wells.

The reservoir model used for planning a multibranch well must capture the delineations of the hydrocarbon-bearing zones, the major axes of the stress regime and the first order controls on fluid flow in the reservoir. This paper illustrates the representation of the three-dimensional visualization of the main reservoir bodies showing the gas, oil and water zones along with the proposed well path. Finally, the reservoir model provides properties of the productive zones to be completed along the well trajectory enabling a forecast of the well productivity for economic analysis.

Once a set of well branches has been envisioned, the well plan proceeds from the reservoir to the surface. For a multibranch well, the main trunk should have a simple trajectory to ensure successful drilling and completion and to enable future access to the branches. From the main trunk the well plan projects an optimal path to the wellhead location. Alternatively, the well plan may accommodate a sidetrack trajectory to a planned branch from an existing well.
A Systems Approach to Production Management: Beryl Field Case Study
Authors: Arnondin M.C. , Jackson M.A.
Published: December 2007

When Beryl Field gas sales commenced in 1992, a production management system was implemented to ensure that gas sales targets were met without compromising oil production rates. This paper describes the operator's experience in establishing this system.

In the Beryl Field, systems analysis techniques are applied in both the data gathering and well modelling procedures. This approach has resulted in significant improvements in both the quality of field data and the accuracy of model predictions. The production system model is used for optimising lift gas allocation, production forecasting for normal and maintenance scenarios and workover planning.

The evolution of the production management system is described and its application to routine operations and special projects is illustrated by examples. The techniques described are general and can be applied to all production optimisation applications.

Introduction

Production optimisation is as much a culture as a technology. For any production optimisation initiative to succeed, the entire organisation must accept responsibility for data gathering and interpretation. This paper describes changes in the operating environment that catalysed the development of this system, along with the operators approach to data acquisition, the management of the collected and interpreted data, well model construction and maintenance practices, and the cultural elements which influenced the Beryl Field optimisation project. The resulting production management system has significantly increased production efficiencies and today, is a reliable component of the Beryl Field design, decision and implementation processes.

Background

The Beryl field, located in Block 9/13 of the UK sector of the North Sea, has produced approximately 650 MMSTB of oil and 700 Bcf of gas since production commenced in June 1976. The Beryl A Condeep structure, which contains the crude storage and loading facilities, has two separation trains each capable of handling 70 MSTB/D of oil, 60 MSTB/D of produced water and 300 MMscf/D of gas. The Beryl B platform, which began production in 1984, has a single separator train with a throughput capacity of 70 MSTB/D of oil, 60 MSTB/D of produced water and 200 MMscf/D of gas. On both platforms, gas compression capacity is the limiting production constraint.

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Waterflood Performance in the Presence of Stratification and Formation Plugging
Authors: Silva Luis F. , Ali S.M. Farouq
Published: December 2007

Waterflooding a stratified formation consisting of communicating layers of different permeabilities poses serious problems of early permeabilities poses serious problems of early water breakthrough and prohibitively high producing water-oil ratios thereafter. One of producing water-oil ratios thereafter. One of the measures widely used for combatting such a situation is plugging of the high permeability zones within the wellbore, upon which large sums are spent annually. One of the purposes of the present study is to demonstrate the present study is to demonstrate the ineffectiveness of formation plugging as a means for correcting the flood conformance.

A two-phase, three-dimensional reservoir simulator, including capillary and gravity effects, was developed, and used to investigate the flood performance under a number of situations involving reservoir permeability variations. The simulator was designed to utilize Stone's newly proposed Strongly Implicit Procedure (SIP), which was found to be more Procedure (SIP), which was found to be more accurate and faster than ADIP in comparison runs. The simulator was tested under a variety of conditions, giving highly accurate material balances and relatively large stable time steps.

Simulations of formation plugging in order to shut off high permeability strata showed that shortly beyond the plugged region the flow behavior is such as if no plugging were present. As a result, the waterflood recovery (at any throughput) is nearly the same as for the unplugged case, the variation with injection rate being negligibly small.

In both the plugged and unplugged cases it was evident that the capillary and gravity effects play an important role in smoothing out the flood profile. Many of the simplified approaches, based upon no flow among the strata and neglecting said effects can lead to highly erroneous results. For instance, in one test the oil recovery as predicted by the simulator in such a situation was three times that predicted by Dykstra and Parson's method. predicted by Dykstra and Parson's method. Further tests were conducted to examine the effect of randomization of core data. It was found that the three-dimensional waterflood performance where core data are assumed to be a performance where core data are assumed to be a random sample of the reservoir is much better than if such data are assumed to represent a layered system. The simulator results point to the need for lateral permeability extrapolations that are intermediate to the above two extremes.
Case History of Successful Coiled Tubing Conveyed Jet Pump Recompletions Through Existing Completions
Authors: Hrachovy M.J. , McConnell M.L. , Damm M.W. , Wiebe C.L.
Published: December 2007

Examples illustrating the effectiveness of coiled tubing conveyed jet pump completions as a remedial repair method instead of traditional workovers are discussed. This completion technique was applied to previously shut in wells in a declining oil field with high workover costs, providing an effective and economic repair method.

Two hydraulically pumped oil wells were shut in due to mechanical problems with damaged downhole hydraulic pump assemblies. This paper describes a method whereby a 3-1/2" tubing packer was used to land 1-3/4" coiled tubing inside the existing 3-1/2" tubing. A 1-1/4" jet pump seated in a pump cavity at the bottom of the 1- 3/4" coiled tubing used high pressure hydraulic fluid to pump reservoir fluids and exhausted hydraulic fluid up the 3-1/2" × 1-3/4" annulus.

Jet pump performance was simulated using a computer model to determine the optimal combination of coiled tubing and jet pump sizes that minimized friction and maximized production. Pump performance curves were compared to the well's inflow performance relationship (IPR) curves to predict well performance and power oil pressure and rate requirements. Several remedial options were compared and analyzed to determine the most economically feasible repair method. Field installation procedures were optimized in the second well, resulting in lower costs.

Introduction

Alaska's Cook Inlet Oil Fields are located approximately 60 miles southwest of Anchorage. Cook Inlet platform locations are shown in Fig. 1. A total of 15 platforms have been set in the Inlet, of which 10 are operated by Unocal Four platforms, Anna, Bruce, Baker, and Dillon rely entirely on downhole hydraulic pumps for artificial lift.

Rig and workover operations are often uneconomic due to high mobilization costs. In 1993, one well on the Baker Platform and in 1994, one well on the Anna Platform were shut in indefinitely due to problems with downhole hydraulic power oil equipment. This paper details the new workover technique that economically returned these wells to oil production.

Description of Hydraulic Power Oil Lift System. Produced oil is the hydraulic fluid used on the platforms. Produced oil from the stock tanks is pressurized to 4000 psi at the surface and is referred to as power oil. A controller on each well controls the rate of power oil pumped down the well's power oil tubing string.

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Designing Under and Near Balanced Coiled Tubing Drilling Using Computer Simulations
Authors: Gu Hongren , Walton Ian C.
Published: December 2007

This paper describes the use of two computer simulation utilities to design underbalanced or near balanced coiled tubing drilling : one is a steady-state design module and the other is a transient wellbore simulator developed for coiled tubing operations. The steady-state design module provides various design parameters for a drilling operation, and the transient wellbore simulator predicts the outcome from a particular design for the entire operation. Simulation results show the desired under or near balance can only be achieved by certain combinations of liquid and gas rates when using foam as the drilling fluid or using gas injection through gas-lift mandrel or parasite string. The effects of cuttings loading, depth of injection point and reservoir inflow on the downhole pressure or underbalance are presented and discussed. A procedure for designing under or near balanced drilling is described and demonstrated with an example using the computer utilities.

Introduction

It has long been recognized that a key to improving the recovery of reserves is to minimize the reservoir damage created while drilling. Thus, the main objective of drilling close to or under balance is to increase the productivity of the well by reducing formation damage due to the invasion of the formation by the drilling fluid and/or fines. Additional advantages of underbalanced drilling are that higher penetration rates are obtained than with overbalanced drilling and the risk of differential sticking is reduced.

Coiled tubing is particularly suitable for under balanced or near balanced drilling because of the improved well control in a coiled tubing system and because coiled tubing allows continuous drilling while maintaining the underbalance.

When planning an underbalanced drilling operation, the magnitude of the desired underbalance is a primary consideration. If the downhole pressure is too low, there may be wellbore stability problems. The amount of underbalance also determines the rate of fluid production from the reservoir and the surface facility should be able to handle the production fluid in the return flow.

After the desired amount of underbalance is determined, the next step is to determine how to achieve this underbalance For normal or high pressure reservoirs, underbalance can be achieved by using water, brine or diesel as the drilling fluid. For low pressure reservoirs, nitrogen or produced gas is used to aerate the drilling fluid and reduce downhole pressure. Two injection methods are often used. One is pumping foam or nitrified fluid down the coiled tubing and into the annulus, and the other is injecting nitrogen or produced gas through a parasite string or through existing gas lift mandrels to aerate the liquid column in the annulus.

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Competing for Energy
Authors: Symonds Edward
Published: December 2007

Growing demand for all forms of energy in the U.S. and abroad will put additional pressures upon the conventional sources of domestic pressures upon the conventional sources of domestic hydrocarbon fuels and stimulate the development of the so-called nonconventional sources - shale oil, tar sands, and gas from oil and coal. Nuclear power will continue its establishment as a major new energy source, helped by possible breakthroughs in the development of breeder reactors and atomic fusion. Competition among customers will focus upon qualities and volumes of energy, rather than upon prices or types of fuel that have been traditional in the U.S.

Text

The fact that the total demand for energy continues to grow no longer comes as a surprise. In this respect, it follows the same trend as most raw materials, although lagging behind that of many types of services and sophisticated manufactures. The surprise arises from the speed at which this growth has been proceeding throughout the world, and the upturn that has taken place in the U.S.

In the non-Communist world as a whole, energy demand has been growing at more than 5 percent annually, and is likely to continue to percent annually, and is likely to continue to do so throughout the rest of this decade. If peace can be re-established and more resources devoted to industrial and agricultural development, this pace will speed up still further, with profound implications for countries which have become accustomed to living on large imports of low-cost energy.

In the case of the U.S., energy growth during the early 60ies, at less than 4 percent annually, showed the signs both of a mature economy and of a market approaching saturation. In more recent years, growth has accelerated to 5 percent annually, and there is ground for belief that a sustained higher growth rate must henceforth be expected.

The main reasons for this belief are that energy use is becoming a more important ingredient in consumer satisfaction, while methods of consumption are becoming less efficient. The spread of air conditioning (now used in about one-quarter of the nation's homes), the need for transportation within even vaster metropolitan regions (three of which may contain half the nation's population before the end of the century), and the continuous expansion of the market for energy-based conveniences (ranging from electric heating to all-terrain-vehicles) are cited as evidence of the former trend.
Possible Sources of Gas from the 31S C/D Shale Reservoirs, Monterey Formation, Elk Hills Field, California
Authors: Hampton Thomas J. , Reid Stephen A. , McIntyre Jana L. , Querin E. Mark
Published: December 2007

Cumulative gas production from the C/D Shale Reservoir significantly exceeds expected gas production as estimated from pressure decline data. Reservoir studies indicate three possible sources: leakage from other reservoirs, unconventional gas resources, and underestimation of original oil in place. Each of these three sources are discussed.
A Partnership in Upstream HSE Technology Transfer
Authors: Olszewski R. E. , Wahjosoedibjo A. S. , Hunley M. , Peargin J. C.
Published: December 2007

The oil and gas industry was for nearly two decades the dominant force in the Indonesian economy and the single largest contributor to the nation's development. Because of the success of Indonesia's long-term development and diversification program, this once-dominant sector today occupies a more equal but still vital position in a better-balanced economy.

The Indonesian government understands the danger to the environment posed by rapid industrial expansion and has enacted laws and regulations to ensure the sustainable development of its resources while protecting its rain forest environment. In 1992, the government oil company approached Chevron and Texaco for assistance in training its Health, Safety, and Environment (HSE) professionals.

The upstream environment, health and safety training program was developed to transfer HSE knowledge and technology to PERTAMINA, PT Caltex Pacific Indonesia, a C&T affiliate, and indirectly, to the entire Indonesian oil and gas industry and government ministries. The four companies have demonstrated the effectiveness of a partnership approach in developing and carrying out HSE training.

During 1994 and 1995, four groups, each consisting of about twenty representatives from PERTAMINA, the Directorate of Oil and Gas (MIGAS), the Indonesian Environmental Impact Management Agency (BAPEDAL), CPI, and Chevron and Texaco worldwide subsidiaries, traveled to the United States for an intensive four-month program of study in HSE "best practices" and technology conducted by Chevron and Texaco experts. As a result, Indonesia today has a corps of about seventy highly-trained HSE experts working in the private and state-owned oil and gas industry, and in critically important government agencies and ministries.

This paper describes the development and realization of The PERTAMINA/CPI Health, Safety and Environment Training Program, outlines subjects covered and explains the methodology used to ensure the effective transfer of HSE knowledge and technology. The paper also offers an evalua-tion of the sessions and presents the plans developed by participant-teams for follow up on their return to Indonesia.
The HSE Management System in Practice-Implementation
Authors: Primrose M. J. , Bentley P. D. , van der Graaf G. C. , Sykes R. M.
Published: December 2007

This paper sets out the necessary strategic issues that must be dealt with when setting up a management system for HSE. It touches on the setting of objectives using a form of risk matrix and the establishment of corporate risk tolerability levels. Such issue management is vital but can be seen as yet another corporate HQ initiative. It must therefore be linked and made relevant to those in middle management tasked with implementing the system and also to those at risk 'at the sharp end' of the business.

Setting acceptance criteria is aimed at demonstrating a necessary and sufficient level of control or coverage for those hazards considered as being within the objective setting of the Safety or HSE Case.

Critical risk areas addressed via the Safety Case, within Shell companies at least, must show how this coverage is extended to critical health and environmental issues. Methods of achieving this are various ranging from specific Case deliverables (like the Hazard Register and Accountability Matrices) through to the incorporation of topics from the hazard analysis in toolbox talks and meetings. Risk analysis techniques are increasingly seen as complementary rather than separate with environmental assessments, health risk assessment sand safety risk analyses taking place together and results being considered jointly.

The paper ends with some views on the way ahead regarding the linking of risk decisions to target setting at the workplace and views on how Case information may be retrieved and used on a daily basis.
The Energy Crisis - A Call for United Action
Authors: O'Connor Lawrence J.
Published: December 2007

"If something can go wrong, it will go wrong," so says Murphy's law.

In the light of the current energy crisis in the U. S., may I submit an amendment to Murphy's law which goes like this: "If a number of separate but interrelated things can go wrong, sooner or later they will all go wrong at the same time."

It is a regrettable fact that all major energy supply sources in the U. S. today are experiencing shortages simultaneously. Some of these shortages, fortunately, are clearly temporary in nature and are already on the way to solution. Others are much more difficult and will be with us for a long time. Here are some of the things that have gone wrong and that contribute to the current national energy crisis.

Coal is in short supply and prices on the spot market have been climbing sharply during the past year and a half. The major cause of this was the fact that the coal industry curtailed its expansion a few years ago in the belief that it would lose part of its traditional electric power generation market to nuclear fuel. This did not happen. There were unexpected delays in the completion of nuclear power plants. To further complicate the coal problem, the Japanese have greatly stepped up their coal purchases from the U. S. Also, a new federal coal mine safety law presented problems for some mines. There was a serious shortage of railroad coal cars last winter when certain shippers found it more convenient to store coal in railroad cars than in dockside coal piles. Coal inventories dropped to dangerously low levels at many electric generating plants. Recently the coal car shortage has eased somewhat and coal inventories at electric plants are back to normal. Yet the over-all plants are back to normal. Yet the over-all coal shortage and high spot prices persist, and there is no assurance that next winter will not see another coal crisis, which could be triggered by coal or rail strike action, extreme cold weather or by some combination of these occurrences. The spot price of coal has risen 56 percent in the last year and a half. This is a phenomenal increase not matched by any other commodity listed on the Dept. of Labor monthly wholesale price index. Such an increase is only partially explained by cost factors. The shift from a buyers' market to a sellers' market in coal is probably more significant.

Another set of unforeseen events has created a serious problem for heavy fuel oil. The U.S. demand for residual fuel oil has accelerated at an unprecedented rate, primarily as a result of coal-to-oil conversions and new oil-burning power plants being placed in service designed to meet new air pollution control requirements. The cost on a Btu basis of heavy oil delivered to east coast ports has risen about 75 percent during the past year and a half, and this does not include desulfurization costs required to meet the new air quality standards. The U. S. is dependent on imports for heavy fuel oil since the refineries of the domestic industry are not geared to producing this increasingly important form of energy.
Environmental Review: Policy and Guidelines
Authors: Van Veldhuizen H. D. , Anderson R. B.
Published: December 2007

The International Finance Corporation (IFC) is the private- sector financing affiliate of the World Bank Group. Because it works solely with the private sector in developing countries, its clientele and its project cycle are very different from that of the more traditional business carried out by the World Bank. Nevertheless, as a member of the World Bank Group, IFC is subject to the World Bank’s broad policies and guidelines regarding environmental and health and safety (EH&S) matters. IFC’s Environment Division is responsible for reviewing prospective investments and the existing investment portfolio for compliance with World Bank EH&S policies and guidelines. This review must be carried out in the context of local laws and regulations as well as the IFC-specific project cycle. The World Bank guidelines are in a period of transition as the World Bank updates its environmental guidelines for various industrial sectors and specific pollutants. The approach taken by IFC to environmental review and to implementation of the relevant World Bank policies and guidelines is described, with special reference to various types of investment in the oil and gas industry. In general, IFC requires all investments to be in full compliance with all relevant local laws and regulations and consistent with applicable World Bank policies. The Bank’s EH&S guidelines are used to evaluate the acceptability of the project’s pollution controls and health and safety practices with respect to broadly defined international norms. Detailed environmental impact analyses carried out by the project sponsor may provide a basis for accepting project-specific standards of performance. Public disclosure of the environmental aspects of a proposed IFC investment is required for all projects. The approach to public disclosure, as well as requirements for public consultation on environmental matters in certain cases, will depend greatly on the type of project and the social and cultural context of the host country as well as its environmental regulations.
The Use of Integrated Management Systems Assessments for Continuous Improvement of EHS Programs
Authors: Wills Thomas L. , Frew John , Hammond David R. , Rafn Christian L.S.
Published: December 2007

Texaco's Tartan Platform located in the British North Sea and the onshore support organization located in Aberdeen provide a case study illustrating how environment, health and safety (EHS) management systems assessments can provide an effective mechanism for continuous improvement of EHS programs. A baseline health and safety assessment of Tartan evaluated the degree of management control in place in 1992. A three-year improvement plan was prepared and implemented using the assessment format as a structure. In 1995, Texaco developed an integrated EHS management systems assessment (EHS MSA) program and conducted an environment, health and safety assessment of Tartan. The EHS MSA results documented the efforts made in the management of health and safety issues since 1992 and form the basis for ongoing improvement efforts that include environmental issues. A discussion of how the MSA methodology addresses the emerging ISO 14001 standard concludes the paper.
Environmental Monitoring Survey in Gemsa Development Lease of the Red Sea
Authors: El Ghazaly Sherif
Published: December 2007

An offshore oil field is located in the Gemsa development lease near the west coast of the Red Sea, 50 km north of Hurgada.

The wells are accommodated at a 3 leg tripod jacket in 20m water depth. The oil produced is exported untreated to treatment facilities onshore. Production commenced end 1991.

The region of extensive coral reef formation is of considerable value in view of nature conservation, scientific studies, recreation and tourist industry and has a vulnerable ecology. The area is largely influenced by strong tidal currents and a prevailing NW wind. Bottom sediments are almost completely composed of carbonate material. The area around the jacket is covered with fine, sediments reflecting the influence of eddy motion.

Bapetco requested the National Institute of Oceanography and Fisheries to carry out an environmental monitoring programme, which started early 1992. Sediment samples were collected from 13 locations according to the recommendation of the Group of Experts on oil pollution of the Paris commission up to 2 km from the wells. This was repeated early collected by a grab sampler from a survey vessel with occasional help of divers. For positioning a single GPS receiver was used. The samples were analyzed in various ways covering both the chemical composition (hydrocarbons, metals, organic carbon) and the bioactivity.

Particulars of the analysis can be summarized as follows:

* Concentrations of petroleum hydrocarbons in all samples were of the same order of magnitude except one location in the immediate vicinity of the platform, still being within the margins of accuracy of the analysis methodology. * Bottom flora and fauna in all samples were consistently rich as far as the variety of species and of the number of individuals within the various species is concerned. The observed change of flora and fauna of metals should be characterised as an improvement rather than as a decline. * The concentrations of heavy metals declined. * Organic carbon content did not show any significant change.

Introduction

The area studied represents a coastal Red Sea water area which is largely influenced by a strong tidal current and the prevailing NW wind. The bottom sediments are composed almost exclusively of carbonate material and the central part around Gemsa Platform SE.4 is covered with fine sediments which reflect the influence of an eddy motion. The bottom fauna and flora showed shells with living organisms as well as the presence of coral reefs, sponges, echinodermata and mullusca. The present study is aimed to investigate the environmental changes which took place in the area.

Materials and Methods

* The sediments samples were collected by a Grab sampler (23 × 42 cm) from 13 stations in the Gemsa area of the Red Sea. * For positioning of the survey vessel a single GPS receiver type MAGELLAN GPS NAV/1000 PRO TM was used.

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Waste Management in Wireline & Testing Operations in India
Authors: Chatterjee A. , McFadden F. , Kumar S.
Published: December 2007

No common definition of waste has been agreed upon in the Oil Industry, what is waste in some countries, represents valuable raw material to a multiude of small industries in others. This paper presents an initiative taken in an offshore field West of India by Schlumberger W&T, with the support of its main client, Oil and Natural Gas Commission, to better manage offshore wastes. International and Local regulations are discussed. Different types of wastes produced by the service company are identified and certain alternative technologies are presented. Finally, the program in place, the results thereof, successes and failures and future prospects are described.
Waste Management and Minimization in the Hugoton Field, Southwest Kansas
Authors: Robb A. J. , Beaty T. D.
Published: December 2007

An effective waste management system, implemented by Mobil in the Hugoton Field, has resulted in reduced potential liability, improved compliance assurance, and decreased overall waste-related costs The drilling waste minimization component of this system, that also includes waste management plans and a waste management certification system, is significant because it represents a successful application of technology previously unseen in the Kansas Mid-Continent area. The entire system is validated by tracking performance indicators focusing on waste volumes and costs.

The key element of the drilling waste minimization initiative is a mechanical solids control system consisting of a semi-closed loop centrifuge flocculation dewatering process that removes solids for burial on location. The system provides environmental (80% reduced waste volumes) and economic (S307M/358 well program) incentives, as well as numerous indirect benefits over conventionally used drilling solids control methods. This initiative was the result of a partnering effort between Mobil and the drilling and mud contractors.
Environmental Risk Management and Preparations for the First Deep Water Well in Nigeria
Authors: Berger Fredrik
Published: December 2007

Statoil is among the leaders in protecting health, environment and safety in all aspects of the business. The evaluations of business opportunities and development of blocks opened by authorities for petroleum exploration, are assessed in accordance with the goals for environmental protection. Progressive improvement of environmental performance is secured through proper environmental risk management. In 1995, Statoil, the technical operator on Block 210 off the Nigerian coast, was the first company to drill in deep waters in this area. An exploration well was drilled in a water depth of about 320 meters.

The drilling preparations included environmental assessment, drillers Hazop, oil spill drift calculations, oil spill response plans and environmental risk analysis.

In the environmental preparations for the well, Statoil adhered to local and national government legislation, as well as to international guidelines and company standards. Special attention was paid to the environmental sensitivity of potentially affected areas. Statoil co-operated with experienced local companies, with the authorities and other international and national oil companies.

This being the first deep water well offshore Nigeria, it was a challenge to co-operate with other operators in the area. The preparations that were carried out, will set the standard for future environmental work in the area. Co-operation difficulties in the beginning were turned positively into a conscious attitude to the environmental challenge.
Synergi and E & P Forum HSE Management System Helps Companies Improve HSE Performance and Reduce Losses
Authors: Grundt Hans Jørgen
Published: December 2007

This paper discusses the use of information on accidents and near-misses to improve HSE performance and reduce losses in Exploration and Production activities. Incidents are considered a result of management system failure. To avoid incidents and recurrence of incidents, companies should adopt an integrated HSE Management System and software especially designed for recording, analyzing and following up events. The E&P Forum has issued guidelines to support current company HSE Management systems and practices Concurrently. the Synergi Project has been established to facilitate experience transfer and effective handling of incidents as part of an integrated HSE Management System. The paper describes how important it is to learn from past mistakes, to have a management system which facilitates the implementation of the required corrective action, and that tools for improved loss control arc available.
A Three-Phase, Experimental and Numerical Simulation Study of the Steam Flood Process
Authors: Abdalla A. , Coats K.H.
Published: December 2007

A numerical model of steam-drive oil recovery was developed and tested. The implicit pressure-explicit saturation (IMPES) technique pressure-explicit saturation (IMPES) technique was used to solve the three-phase fluid flow equations for compressible fluids. A method was developed and applied to determine the temperature and the rate of steam condensation implicitly from the heat-balance equation. Both techniques were used in computer simulators for linear and two-dimensional systems.

A steam-injection experimental study was performed in a linear model. The results of performed in a linear model. The results of this experimental work showed good agreement with the results obtained from the linear numerical computer simulators. The results from the two-dimensional numerical computer simulator was also found to be in good agreement with published two-dimensional experimental results. published two-dimensional experimental results. The numerical simulators were also used to study the effect of some parameters on the steam-drive process. It was found that numerical model results were very sensitive to capillary pressure values. It was also found that the relative permeability data has a minor effect on the results obtained. The oil viscosity was found to affect the process to a large extent. Oil recovery from steam-drive process decreases as the oil viscosity increases process decreases as the oil viscosity increases Also, the recovery curves for low viscosity oils show earlier steam breakthrough than those with higher viscosity.

Introduction

The first part of the work presented here is a physical laboratory model of steam injection in a linear system. A constant pressure boundary condition was used. Two runs were performed on the same model using two different performed on the same model using two different sets of injection and production pressures. Oil recovery and temperature distribution data were obtained. Each run was repeated to check reproducibility of results.

The second part of this work describes the development and application of numerical simulation techniques to solve equations describing the steam-injection process. This simulation model was the implicit pressure-explicit saturation technique to pressure-explicit saturation technique to solve difference equations describing the multiphase flow system. The solution of the heat-balance equation yields the temperature ahead of the steam front and the rate of steam condensation behind the front.
Petroleum Industry and Environment in Socialist Republic of Vietnam
Authors: Huynh Nguyen Duc
Published: December 2007

Can be divided into 3 stages: Before 19751975 – 19811981 till now

Principally in the plain of Red river (volume of more than 40 wells). Southern continental shelf (some drilling wells of Companies of MOBIL, PECTEN etc&).

Appraisal, development and exploitation of Tien Hai C gas field. In the Red River Delta. Exploration in Mekong Delta (2 wells). PSC signed with Deminex, Agip and Bow Valley (12 wells).
Permeability, Cementation and Grain Size: A Deductive Inquiry
Authors: Thomere Roland , Potter Paul Edwin , Sternberg Yaron M.
Published: December 2007

Our objective is to deductively and semi-quantitatively explore the joint effects of grain size and flow on cementation rates and thus on the permeability of sandstones. For example, is it safe for a reservoir geologist to assume that a map of grain size is a good predictor of permeability in a reservoir? predictor of permeability in a reservoir? grain size only of value when one can independently specify a reservoir's history of pale flow? Or conversely, are there any cementation patterns that imply a unique pattern of patterns that imply a unique pattern of paleoflow? paleoflow? The basic equation is

dS/dt = Au,

where S is the cumulative volume of cement deposited per unit volume of sandstone; t is time; a is a dimensionless constant of proportionality depending upon temperature, proportionality depending upon temperature, temperature gradient, pressure, dissolved solutes, etc.; A is the internal surface area per unit volume of sandstone, and u is the velocity of flow. Solutions to this equation suggest that paleoflow needs to be specified before grain size can safely be used as a predictor of the permeability distribution of a sand body.

Numerical models and computer studies may be useful in expanding our understanding of cementation patterns in sand bodies and the relation between grain size and rate of cementation.

Introduction

A sandstone consists of grains, cement, mud and a pore system (Fig. 1). The grains of sandstone provide its essential framework or skeleton and thus define its pore system. This pore system may be wholly or partially filled by pore system may be wholly or partially filled by mud at the time of deposition or later wholly or partially filled by a chemically precipitated partially filled by a chemically precipitated cement. Pressure solution - the development of microstyolites at points of contact between grains - may also contribute to later reduction of pore volume.

Adams first called our attention to the effect of grain size on cementation and permeability of sandstones. He noted that in the permeability of sandstones. He noted that in the near-shore marine Pennsylvanian sandstones of Oklahoma the silts had virtually no permeability but that the interbedded sandstones had a variable permeability. The silts in the Cambrian-Ordovician Hassi Messaoud sandstone in Algeria behave similarly. Here thin, interbedded siltstones are almost completely cemented by silica and show abundant pressure solution and have negligible permeability, whereas permeability in the interbedded sandstones, can be appreciable (Fig. 2).
The Market for "Greener" Chemicals
Authors: MacFarlane Timothy
Published: December 2007

Increased regulation in the North Sea area calls for the use of less toxic chemicals in the oilfield industry. European countries with interests in the North Sea are beginning to require the use of these "green" chemicals to prevent further environmental damage.

The Oslo/Paris Commission (OSPARCOM), which will become the official regulatory body for 22 European member countries in 1997, dictates that each member country is responsible for enforcing OSPARCOM regulations. Some countries more stringently apply the regulations than others.

To meet the standards of the regulations, service companies need to evaluate their existing chemical lines and determine which products meet the environmental regulations. The concept of Best Available Technology (BAT) offers companies a way to keep up with continuing changes in environmental regulations. The regulatory agencies for each country provide recommendations on the supply, use, and disposal of chemical products to minimize the discharge of hazardous substances.

As "greener" alternatives become more widely required, manufacturers and oilfield suppliers will have to work together to produce chemicals that meet both environmental regulations and the needs of the oil field. This relationship between the need to develop technological solutions and the BAT can generate a substantial market for "green" chemical substances.
Development and Management of a Large Gas Field by a Computer Simulation
Authors: Sharp D.A. , Arndt H.A. , Coats K.H.
Published: December 2007

This paper discusses the application of an integrated gas-field simulation system to evaluate deliverability designs and operating strategies. The system simultaneously considers the three interacting pressure drops one encounters in a gas gathering system.

Thus the actual backpressures and deliverability as a function of the movement of gas through the entire piping system are obtained. This integrated approach to gathering system design and field development allows rapid evaluation of the various alternates.

The operating system simulated is a large, middle-aged gas producing property located in Alberta, Canada. The primary study area consists of the property owned by Saskatchewan Power Corporation. However, due to the extent Power Corporation. However, due to the extent of the producing horizon, the study area included property not owned but adjacent to the property owned by Saskatchewan Power Corporation. The objectives of the study are to evaluate the feasibility and economics of maintaining the peak deliverability at contract demand for a period of ten years in the future and the development of a field operating strategy to minimize required investment and minimize or eliminate gas drainage across lease boundaries. The results of these objectives are presented. Additionally a comparison technique for various deliverability design alternates is presented. Finally, a discussion of the installation and utility of the integrated system on a small computer is included.

Introduction

It has long been recognized that gas well deliverability is a function of the three pressure drops, in the reservoir, in the pressure drops, in the reservoir, in the production string and in the surface piping production string and in the surface piping and compressor configuration. Actual gas well deliverability and, consequently, total field deliverability can be computed only when all three pressure drops are considered simultaneously. Because each of the pressure drops is associated with a different flow system, three different simulation equations are involved. To perform rigorous compression studies, reservoir studies or gas gathering system design, one must integrate these three simulation segments in such a manner that the flows and pressures balance at each node in a multiwell gathering system.