bluuebunny/crossref_metadata_2025 huggingface dataset:
A New Approach to High Temperature Drilling Fields
Authors: Carney Leroy L. , Meyer Robert L.
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

The clay mineral sepiolite has been under investigation since 1972 by our laboratories for possible use in drilling fluids. This paper reviews the work done on this clay mineral in an effort to obtain a drilling fluid capable of withstanding temperatures in the ultra high range. This includes a study on the rheology of sepiolite slurries that have been subjected to temperatures up to 800 deg. F. X-ray diffraction techniques and scanning electron microscope studies were used to examine the crystalline structure of the sepiolite before and after exposure to these high temperatures. There appears to be some changes in the sepiolite after being subjected to temperatures up to 800 deg. F. However, the basic structure seems to be stable. Data is given showing that slurries prepared from sepiolite and other additives have favorable rheological and fluid loss properties over wide temperature ranges. properties over wide temperature ranges

Introduction

Sepiolites belong to a group of magnesian silicates, with a fibrous texture, whose idealized formula can be written Si12Mg8O32nH2O. This mineral is believed to have microporosity, giving it a unique place in the clay mineral family because of its structural characteristics and physics-chemical properties.

Sepiolites derive much of their commercial value from their molecular sized channels and grooves. The channels are lost when the crystals fold, which occurs when the temperatures are elevated and water is driven out of a dry sample of sepiolite. The conditions necessary for folding and the stages and mechanism of this change are only partially understood. Our studies show that when a sepiolite slurry is subjected to elevated temperatures, the channels take on water and swelling occurs.

In our studies of slurries containing sepiolite, it was observed that the rheological properties of the slurries showed a slight increase in viscosity when measured at elevated temperatures and pressures. Due to this apparent temperature stability, formulations containing sepiolite were prepared and tested at these extreme conditions. Parameters that are important for good drilling fluid performance were measured and recorded.

CHARACTERISTICS OF SEPIOLITE AS A CLAY MINERAL

Reports are available on various studies conducted on sepiolite and related clay mineral. Sepiolite deposits and sepiolite/attapulgite deposits have been used in Europe for saltwater clays in drilling muds in lieu of attapulgite normally used in the United States. Oil Companies Materials Association specifications for salt-water drilling clays include sepiolite. At the present time, the API does not recognize sepiolite as a saltwater clay for drilling fluids.
Transient Pressure Analysis for Partially Penetrating Wells in Naturally Fractured Reservoirs
Authors: Bui T. D. , Mamora D. D. , Lee W. J.
Published: December 2007

This paper presents an analytical solution that describes transient pressure behavior of partially-penetrating wells in naturally-fractured reservoirs. The solution is obtained by combining the pseudo-steady state model for naturally fractured reservoirs with the partially-penetrating well model in homogeneous reservoirs. Verification of the analytical solution is made by comparison of pressures derived analytically with those obtained from numerical simulation. The new type curves generated from the analytical solution indicate that partial penetration and double porosity effects cause a characteristic shape of the curves at early and transition time. The type curves may be used to analyze transient well test analysis for partially-penetrating wells in naturally-fractured reservoirs at early and transition time.
Using 3D Seismic To Identify Spatially Variant Fracture Orientation in the Manderson Field
Authors: Gray F. David , Head Kim J.
Published: December 2007

Oil is produced from the Manderson Field, in Big Horn County, Wyoming, from a fracture system with possible significant lateral connectivity. So characterizing the fractures in this field is of great importance. Amplitude Versus Offset (AVO) and Azimuth (AVAZ) analysis of 3D seismic data is used to determine fracture strike and density at well locations in the Manderson 3D. The result of the analysis described in Gray et al (1999) is compared to fracture strike analysis from oriented cores for three wells within the Manderson 3D, to outcrop analogues and to outcrop at the Zeissmann Dome, 10 miles to the SE of Manderson Field.
Using Deltaic Models and Petrophysics of Shales to Find More Permeable Areas in Fields Near the Rockies
Authors: Allen Rob L.
Published: December 2007

Well log sand responses have been routinely used to make maps. However, maps of shale responses can detect and display details about geologic components within sedimentary systems. Additional depositional properties from shales helped to identify and utilize appropriate deltaic analogs. More effective models for locating permeable zones have been created for fields within a large area extending from near the Canadian Rockies to Mexico.
Application of After-Closure Analysis for Improved Fracture Treatment Optimisation: A Cooper Basin Case Study
Authors: Chipperfield Simon T. , Britt Larry K.
Published: December 2007

Fracture stimulation is a technique used to improve production in many oil and gas fields around the world and its application has resulted in significant economic benefit. Further economic gains can be achieved by obtaining both an improved understanding of the reservoir description and enhancing fracture model calibration.

Accurate reservoir description, specifically permeability (k) and permeability thickness (kh), is required for optimising fracture design and execution. As a result, development and/or application of techniques to determine the reservoir description prior to fracture stimulation are of paramount importance. Fracture model calibration, the other major facet of hydraulic fracture optimisation, is achieved by the interpretation of pre-fracture diagnostic injections. Improving the ‘uniqueness’ of these interpretations is thus another key area for enhancement.

With a view to strengthening these two aspects of fracture optimisation and providing measurable economic improvement, After Closure Analysis (ACA) has been studied for its applicability in Cooper Basin tight gas reservoirs by conducting a hindsight evaluation of historical pre-frac "mini-frac" calibration tests.

This paper documents the review of the extensive multidiscipline (completion, stimulation, and reservoir) Cooper Basin database to assess the viability of ACA to determine both reservoir permeability prior to fracture stimulation as well as to improve the uniqueness of pre-frac injection evaluation. Finally, this paper will use the historical perspective of the database review to develop both data collection and application guidelines for ACA.
Experimental Study of Hydraulic Fracture Conductivity Demonstrates the Benefits of Using Proppants
Authors: Fredd C. N. , McConnell S. B. , Boney C. L. , England K. W.
Published: December 2007

Hydraulic fracturing treatments using treated water and very low proppant concentrations ("waterfracs") have been successful in stimulating low-permeability reservoirs. However, the mechanism by which these treatments provide sufficient conductivity is not well understood. To understand the effects of hydraulic fractures on conductivity, a series of laboratory conductivity experiments were performed with hydraulically fractured cores from the East Texas Cotton Valley sandstone formation. Jordan sand and sintered bauxite proppants were used at concentrations of 0, 0.1 and 1.0 lbm/ft2, and the conductivity was measured at effective closure stresses ranging from 1,000 to 7,000 psi.

The results of this study demonstrate that fracture displacement is required for surface asperities to provide residual fracture width and sufficient conductivity in the absence of proppants. However, the conductivity may vary by at least two orders of magnitude depending on formation properties such as the degree of fracture displacement, the size and distribution of asperities, and rock mechanical properties. In the presence of proppants, the conductivity can be proppant or asperity dominated, depending on the proppant concentration, proppant strength and formation properties. Under asperity dominated conditions, the conductivity varies significantly and is difficult to predict. Low concentrations of high-strength proppant reduce the effects of formation properties and provide proppant dominated conductivity. At conventional proppant concentrations, conductivity experiments performed with flat, parallel core faces tend to overestimate the conductivity observed with hydraulic fractures. Actual hydraulic fracture conductivity may be as much as an order of magnitude lower in the presence of low strength proppant. An important implication of this study is that the success of a "waterfrac" treatment is difficult to predict because it will depend significantly on formation properties. This dependence can be overcome by using high strength proppants or proppants at conventional field concentrations.
Water-Rock Interactions in the Pembina Field, Alberta
Authors: Melrose J.C. , Johnson W.F. , George R.A. , Groeneveld H.
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Chemical analyses of produced water samples from the Pembina Field, Alberta, are used to develop new insights relating to water-rock interactions within the reservoir. Samples from areas of the reservoir subjected to extensive flushing with fresh water show that the dilution of formation water is accompanied by a substantial increase in the concentration of NaHCO3. In order to provide an explanation for the NaHCO3 build-up, a simple chemical model of the reservoir has been developed.

Introduction

A description of a polymer pilot flood in the Pembina Field, Alberta, has been given in a previous paper. Chemical analyses of produced water samples from this pilot flood produced water samples from this pilot flood provided evidence for the occurrence of provided evidence for the occurrence of water-rock interactions within the reservoir. The data indicated that the effective salinity of samples from an area of the reservoir subjected to extensive flushing with fresh water is maintained at an equivalent NaCl concentration of about 0.2 percent. A comparison with analyses of produced water samples from other areas of the field has shown that the salinity persistence effect observed in the polymer pilot area is of general occurrence in the pilot area is of general occurrence in the Pembina reservoir. Pembina reservoir. The effect appears to be due in part to the commingling of formation water with the fresh injection water, either within the reservoir or in the producing wellbores. However, the resulting dilution of the formation water is accompanied by a substantial increase in the concentration of NaHCO3. In an attempt to provide an explanation for the NaHCO3 build-up, a simple chemical model of the reservoir has been developed. This model and based on the premise that the pore fluids, both oil and water, will tend to reach chemical equilibrium with all of the mineral phases present in the reservoir. The model predictions are in agreement with the observed relationships between Cl and HCO3 concentrations. This implies that the commingling of formation and injection water may take place primarily within the reservoir.
Maximum Permissible Drillbit Weight from Drillcollars in Inclined (Directional) Boreholes
Authors: Mitchell B.J.
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

A discussion of the buckling of drill collars and drillpipe in inclined (directional) boreholes is presented for the purpose of selecting maximum drillbit weights from drill collars such that the section of the drillpipe within the drillstring above the drill collars will not be buckled. The theories of A. Lubinski, R. Hoch, and the work of M. Rollins pertinent to drill-collar applications are pertinent to drill-collar applications are reviewed. The mechanics of drill-collar and drillpipe bending and buckling in inclined boreholes and long-standing misconceptions are discussed. A mathematical equation for the analytical calculation of a maximum permissible drillbit weight from drill collars in inclined (directional) boreholes is derived and presented with solved example problems. A convenient nomograph is given.

Introduction

Drill collars are a major component of the drillstring within the rotary drilling system. They are thick-walled, hollow steel tubes about 30 ft in length with thread connections at either end. A series of drill collars within the drillstring are called a drill-collar string and the common lengths of a string are between 90 and 500 ft. Common wall thicknesses are between 1 and 4 in., which yields linear weights in the range of 20 to 368 lb/ft. The drill-collar string may weigh as much as 100,000 lb. It occupies a position within the drillstring between the drillbit and the drillpipe.

Drill collars were introduced in the Seminole oil fields of Oklahoma in the early 1920's for the purpose of maintaining more vertical boreholes. More vertical boreholes give higher assurance that boreholes will remain within lease boundaries, penetrate the correct location within the geologic structure, and reduce interference between wells during drilling and producing operations.

For three decades the selection of drill-collar strings with respect to their diameters and lengths was an art given to errors arising from misunderstood concepts and misinterpreted experiences. In 1950, Lubinski published his paper, "A Study of the Buckling of Rotary paper, "A Study of the Buckling of Rotary Drilling Strings," which placed drill-collar string selection into the realm of science. His theory is often called the "pendulum theory", or the "one-stabilizer theory" and contends with the problem of analytically aggregating the following variables pertaining to drill collars and the earth's structure:
Full-Scale High-Pressure Stripper/Packer Testing with Wellhead Pressure to 15,000 psi
Authors: Andersen J. N. , Rosine R. S. , Marshall M.
Published: December 2007

The oil and gas field industries continually challenge the limitations of coiled tubing (CT) equipment. With an increasing amount of high-pressure work developing for CT, validating components for this work is a challenge. One component in particular, the stripper element, is of interest. Many manufacturers of tubing strippers rate their components for working pressures from 10,000 to 20,000 psi, but limited test data is available for element wear or resiliency at these pressures.

This paper presents results from full-scale testing of a stripper/packer element at pressures as great as 15,000 psi. Various elements were tested for longevity, internal material integrity, and safety at high to ultrahigh pressures. As a result of the evaluation, (1) the stripper/packer was validated to 15,000 psi, (2) a suitable packing element was developed and tested, and (3) operational guidelines for high-pressure work were developed for the field.
A Hybrid Milling/Jetting Tool - The Safe Solution to Scale Milling
Authors: Eslinger David , Johnson Ashley B. , Mcdonough Aaron , Oettli Mark
Published: December 2007

We present a comprehensive wellbore cleanup toolbox, which combines and optimizes the benefits of jetting, milling and chemical dissolution techniques. The system will clear obstructions from the wellbore and clean back to the tubing wall in a safe non damaging manner.

Conventional cleanup techniques use wash tools, which are inefficient, solvent bullheading which is poorly targeted and wastes reagents or milling tools which can be damaging to the wellbore. These present a less than optimized solution to a commenly occurring problem.

We have developed a tool box which includes an optimized jetting tool for cleaning out soft and weakly consolidated materials. It also presents benefits when used with solvents, or chemical reagents by delivering the fluids directly into the blocking or plugging obstructions with sufficient energy to accelerate the dissolution process and minimize the fluid consumption.

For insoluble materials with a clearance hole we use a self powered jetting tool with the non damaging, Sterling Beads, abrasive system. This will remove scale or other obstructions from the well without damage to the wellbore or jewelry.

For hard and insoluble bridges or plugged wellbores we use a hybrid jetting and milling system. Using a modified PDM with a radial jetting head and small PDC mill. The mill is sized to be smaller than the tool so it cannot contact the tubing or jewelry. Hence the system is safe and non damaging. In addition by using a smaller mill the drilling torque is reduced and the system is more reliable than an equivalent conventional system.
Practical Considerations for Enhancing Coiled Tubing Well Control Operations
Authors: Sas-Jaworsky Alexander
Published: December 2007

Concentric tube well servicing technology is employed in numerous applications where pressure and fluid containment must be controlled at the surface. By design, the primary mechanism for maintaining pressure and fluid containment in these types of concentric-tube services is the purpose-built well control stack working in combination with fluid flow control devices in the surface treatment piping. As such, concentric tube well servicing systems have a unique advantage in that they are not bound by use of balance-weight fluids to maintain pressure and flow control as employed in conventional jointed-pipe rig systems.

However, when service conditions dictate that well pressure be at balance at the surface, well control practices which focus on fluid hydrostatics must be employed. Although based on the processes used in conventional jointed-pipe rig systems, coiled tubing well control practices performed concentric to existing well tubulars are more complex and require greater attention in design and implementation.

This paper provides an overview of the recommended coiled tubing well control stack and flow control device configurations for defined pressure control conditions and offers practical approaches which address the various concerns unique to coiled tubing well control applications.
Optimizing and Managing Coiled Tubing Frac Strings
Authors: Kazakov Serguei , Rispler Keith
Published: December 2007

Multizonal coiled tubing fracturing (CT frac) services have been successfully performed in shallow gas fields in western Canada for more than I year. Properly managing and designing the serviceability of CT strings is critical to these operations.

This paper discusses the practical and theoretical aspects of optimizing the frac-string design, changing the equipment geometry of the CT units, and using a CT fatigue model and fatigue-simulation software. The paper also discusses factors affecting the longevity and performance of frac strings, programs for continuously monitoring the service life of the strings, and actions considered for recovering and extending the fatigue life.

With a properly designed and implemented comprehensive tubing management program, service operators in western Canada have helped ensure a high degree of personnel safety during fracturing while minimizing the risk of CT failure and maximizing pipe life.
A Concept of a New Steerable Drilling System for Coiled Tubing
Authors: Maranuk C. A. , Gaynor T. M. , Chen D. C-K , Pruitt J.
Published: December 2007

Conventional PDM (Positive Displacement Motors) are widely used in coiled tubing drilling jobs. PDC bits are often used with the PDM’s because of their longer life, increased ROP, and increased steerability. But conventional PDM-PDC bit systems often create hole problems and high vibrations that result in casing running problems, downhole equipment failure and lost drilling time.

A new steerable assembly has been designed that provides significant advantages over conventional steerable assemblies. The new system comprises of uniquely designed pin-down mud motor with a specially designed long-gauge PDC bit in a matched drilling system. To date, field results from the new system have shown to improve hole quality and increase ROP. Other advantages include less hole spiraling and tortuosity, reduced vibration, better steerability and hole cleaning, increased bit life, and improved PDM and MWD reliability. These benefits are expected to have considerable implications for coiled tubing drilling applications.
Expandable Wellbore Tubulars
Authors: Stewart R. B. , Marketz F. , Lohbeck W. C. M. , Fischer F. D. , Daves W. , Rammerstorfer F. G. , Böhm H. J.
Published: December 2007

The development of expandable tubular technologies was initiated by the business need to reduce drilling costs, to increase production of tubing constrained wells and to enable operators to access reservoirs that could otherwise not be reached economically without using expandable wellbore tubulars.

Expanded casing applications concentrate on reducing the telescopic profile of well designs. Casings and liners can be expanded against the previous casing/liner in such a way that each time they are set, the well diameter is just reduced by two tubular wall thicknesses. Furthermore, expandable wellbore tubulars also give life to existing wellbores through capabilities for selective water shut-off, damaged casing and tubing repair or for increasing burst and collapse ratings by cladding the inside of casing and tubing.

Yard tests have shown that it is possible to expand tubulars by up to 40 pct in diameter at a rate of up to 100 [ft/min] by means of propelling ceramic headed or hardened steel mandrels. The critical success factors for unconstrained expansion and cladding of wellbore tubulars and their implications for downhole applications will be addressed.

The development of commercial products for use in the oil-field requires the complementary capabilities of both service and operating company personnel. A novel type of technology commercialization concept has been established to provide the technology to the Industry through two fifty-fifty joint venture companies between an operator and major service companies.
A Corporate Planning Model for the Prediction of Exploratory Success
Authors: Gayden G.W. , Dalto S.J.
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Described herein is a model developed for use in corporate long-range planning. The model projects future income from and development projects future income from and development capital required for discoveries resulting from current and future exploration expenditures. Risk is implicitly considered. It is designed for use by top management and provides a tool by which various exploration strategies can be tested and their sensitivities measured.

Introduction

One of the more important tasks any oil and gas company faces when developing long-range plans is estimating the impact, both financial plans is estimating the impact, both financial and operating, of discoveries resulting from current and projected exploratory expenditures. Such an estimate is necessary in determining whether the expected results of these expenditures will conform to corporate goals and objectives. Also, the estimate will show whether the capital required for development of exploratory successes will unduly strain the company's capital structure. Described herein is a model constructed solely for the purpose of deriving such estimates. This model, entitled the Exploration Success and Production Development Model (ESM), has been used by Aminoil USA, Inc. for several years and has substantially improved our planning. It should be stressed that ESM is a planning tool, not an evaluation tool.

Before describing ESM, we should first discuss other methods of achieving the goal for which it was developed. We have reviewed industry publications, but have not discovered any articles dealing with this specific subject. Many articles have been published discussing methods of evaluating specific exploration prospects, projects, and/or geological/ prospects, projects, and/or geological/ geographical areas. None of these, however, are truly appropriate for the micro-type problem described above. Thus, other approaches need investigation. Intuitively, it would appear that the best method of deriving the required estimate would be to evaluate each extant exploratory project individually and sum the results. However, for even moderate size companies, this approach entails several problems such as (1) the process would become problems such as (1) the process would become extremely cumbersome as the number of projects increased, (2) the sum of the individual projections would likely be optimistic, (3) it would projections would likely be optimistic, (3) it would be difficult for top management to exercise effective control, (4) sensitivity analysis due to changing geopolitical conditions would be difficult, and (5) the question of unspecified future projects remains to be answered.
Evaluation of Dry Hole Probability Associated with Exploration Projects
Authors: Wansbrough R.S. , Price E.R. , Eppler J.L.
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

A number of authors have discussed the application of Monte Carlo simulation methods to the economic evaluation of exploration ventures. The ultimate results of such simulation will be directly proportional to the dry-hole risk associated with the venture. This paper deals, first, with a method of evaluating dry-hole risk and, second, with a method of minimizing the impact of bias or emotion on the probability estimates used.

It is suggested that the occurrence of hydrocarbon reservoirs requires the simultaneous occurrence of a means of entrapment, porous and permeable rock, and hydrocarbon accumulation. permeable rock, and hydrocarbon accumulation. With respect to an individual prospective hydrocarbon reservoir, the probabilities of each of these events will be independent. In evaluating the probability of occurrence of any one of these events, the explorationist may have more than one independent analytical method at his disposal. To evaluate the probability of occurrence of accumulation, for example, the explorationist may have statistical data regarding the occurrence of hydrocarbons in traps within a particular formation, and may also have "bright spot" or seismic amplitude data that each provide independent indications of an accumulation in the prospect considered. The method proposed makes use of statistical-set theory, first, to combine independent indicators of each of the required three events (trap, porous and permeable rock, accumulation) and, porous and permeable rock, accumulation) and, second, to evaluate the probability of the simultaneous occurrence of the three events. Once dry-hole risk is determined, Monte Carlo simulation methods, widely discussed in the literature can be used to determine an "expected value" and a profitability distribution for the successful ventures.

Also proposed is a method that the authors believe may tend to reduce the impact of bias or emotion on the necessarily subjective probability estimates used. A "check list" has been devised to arrange possible indicators of entrapment, rock characteristics and accumulation in a probability related order. Use of the check list probability related order. Use of the check list tends to reduce the range of probability estimates that might be made by different explorationists if a less structured approach were used.
Comparative Economics of Oil Field Development Projects in Several Overseas Areas
Authors: Vadgama Usman N.
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Economics of overseas ventures are very dynamic and are a function of the interplay of numerous variable parameters. These differ from corporation to corporation and from country to country. This article attempts to limit the variables in order to obtain specific answers concerning project economics under various overseas contract arrangements.

Based on a hypothetical offshore oil field containing half a billion barrels of stock tank oil reserves, and assuming representative development and operating costs, economic analysis is undertaken. Three types of overseas operating terms are considered: Conventional OPEC type, Production Sharing Pertamina type and UK-North Sea type. Pertamina type and UK-North Sea type. Sensitivity analysis is presented using variables like oil price, production rates and reserves, royalty and tax rates, development and operating costs, and delay in production start-up.

Introduction

"It's a year of transition for offshore oil...... The bargaining table became the new area for exploration on almost every continent on the globe. Talks continued for months on end. Within individual countries, government officials argued against themselves, slowly formulating new economic policies and terms regarding a newly prized policies and terms regarding a newly prized possession - energy" possession - energy" Offshore, June 20, 1976

"West's Oil Firms Seek to Alter Iran Pacts" The Wall Street Journal, Jan. 23, 1976

"The Greek government has asked companies holding exploration licences to negotiate revision of license terms"

Ocean Oil Weekly Report, May 5, 1975

"Indonesia Demands an Increased Share of Oil Firm's profits Retroactive to Jan. 1".

The Wall Street Journal, Jan. 23, 1976

These and similar items have recently been making headlines in business magazines.
Environmental Management System of the Bolivia-Brazil Pipeline Project
Authors: Beasley Kay P.
Published: December 2007

The Environmental Management System of the $2 billion Bolivia-Brazil pipeline project is unprecedented in Latin America. Key elements included a supervision scheme for monitoring construction activities and a management organization for administering extensive communication and compensation programs for indigenous as well as non-indigenous communities. The project was confronted with some of the world's most ecologically sensitive regions, limited infrastructure, indigenous populations, bi-national government interests, and complex partnership arrangements. In spite of these challenges a unique and effective system was developed which can be extrapolated to future projects striving for higher standards of environmental performance.
Maximising Safety Performance Despite the Client/Contractor Relationship
Authors: Allwright Tony
Published: December 2007

Notwithstanding goodwill, good intentions and good attitude on all sides, the relationship between the client and his contractors often acts as a blockage to the further improvement of safety performance. Removing this blockage represents a golden opportunity to achieve the next significant breakthrough in safety performance by enhancing and maturing the relationships and mutual understanding between the different companies in an operation, and at all seniority levels. Though demanding much personal effort, especially from managers, it is a low-cost high-impact approach. Technical performance will also be enhanced by the same process.

Contractors need to develop and propagate their own safety identities, apply their own solutions and totally believe in what they are doing, albeit in full cooperation with their clients. But this in turn demands that the clients understand and respect the needs and contribution of the contractors and sub-contractors, as well as their own limitations.
The Villano Field - A New Approach to Environmental Studies in Ecuador
Authors: Alemán Miguel Angel , Méndez Sixto
Published: December 2007

The environmental studies were developed taking into account the different environmental factors or different components of the abundant biodiversity and important ethno-cultural wealth. From which the project's design phase assigned great significance to the environmental variable on which decisions are based on the study of alternatives and site selection for the different facilities.

Selection of the flow line and secondary oil pipeline routes, construction techniques, leading-edge technology, and the equipment required to comply with actual environmental requirements, were all analyzed and discussed during the project's environmental feasibility phase. In like manner were studied variants for crossing populated areas, where the socio-ethno-cultural component holds significant weight. Passage through the Guacamayos mountain range and the Antisana Ecological Reserve were the final challenge for the design and environmental feasibility stage.

All the alternatives should conform to a single objective; minimize environmental impacts to the zones or areas defined as highly sensitive, and obtain consensus acceptance from the social actors within the project's area of activities.

It is important to point out that the participation of government organisms, indigenous associations, and settler organizations, provided important contributions to the Environmental Studies. The intervention of Environmental Technical Committee, made up by members of OPIP, ASODIRA, AIEPPRA, Petroecuador (Ecuadorian Government owned company) and ARCO/AGIP in the entire Environmental Study process, in fieldwork as well as elaboration of the report was essential, chiefly in obtaining consensus for the elaboration of the Community Relations Plan.

The designed Environmental Management Plan takes into account all norms, specifications, plans, and programs required for construction and operations phase compliance with environmental standards, national as well as international (World Bank mainly), including the specific and special characteristics of the Project's area of influence. The Oil Spill Contingency Plan, and the Sensitive Areas Map is an essential contribution to the project's operational phase, where the geographic information system (GIS) becomes a basic tool of this Plan.
HIV Infection Among Cabinda Population and the Role of an Operating Company to Reduce HIV Infection through Blood Transfusions
Authors: Gama A. S. , Cruz A. S. , Oliveira M. S. , Tibúrcio J. A.
Published: December 2007

AIDS was the first cause of reported death (47%) among adults and children at CABCOC clinics between 1997 - June 1999. In the last 10 years, 863 HIV seropositives were reported among CABGOC employees and their relatives. Between 1988-1990, 24% (15/62) of all diagnosed HIV seropositives, had a history of blood transfusion. The aims of this study are to investigate trends of HIV infection and to assess the impact of Company supported blood-screening program, at the main Hospital of the National Health Service. Despite a significant reduction in the new HIV seropositives diagnosed at the CABCOG medical unit, with history of blood transfusion in Cabinda in the last 7 years, from 20% to 1% (p<0.0000), HIV/AIDS is still an increasing public health problem in Cabinda, particularly among youth and females and is causing a burden for the health and socio - economic sectors
Malaria in Cameroon -- Support for a Survey Crew
Authors: Moreau Jean-Marie , Huebner Wendy W.
Published: December 2007

A comprehensive malaria control program was implemented during land survey activities for an oil pipeline project in Cameroon. Data were collected using a field-based health reporting system. Malaria control measures were instituted and effectiveness was compared among different groups of workers in different locations. The most valuable control measures appeared to be the access to early diagnosis and treatment. Productivity losses due to debilitating illness were reduced and no malaria dealths occurred.
Amine Contactor Benzene Emissions Reduction Project in East Baton Rouge Parish, Louisiana
Authors: Mustard D. G. , Rios A. G.
Published: December 2007

Early in 1996, two Amoco Natural Gas Treating facilities in the Louisiana area were determined to be major sources of HAP's (hazardous air pollutants). Internal emissions testing determined that the two facilities, both with amine contactors used to reduce the CO2 content of the natural gas stream, were major sources of benzene emissions. Two options were evaluated to control the emissions: 1) thermal oxidation and 2) a newly developed process of using stripping towers to remove the benzene.

Thermal oxidation was a proven process with a high installation cost and high annual maintenance costs. The second option involved passing the rich amine countercurrent to sweet gas (used for fuel gas) in a stripper tower. The capital cost was significantly less, with essentially no annual costs. The second option was selected and a pilot built. Initial tests were conducted in early 1997 and results were encouraging, proving the process worked, but the benzene removal efficiency needed to be higher. A number of design changes were implemented and a second test resulted in acceptable (72%) efficiencies The Louisiana Department of Environmental Quality established the MACT level for this process at 70%, based on pilot results. A full scale system was then installed and brought on-line and is currently operating at 74% efficiency, with potential for continued improvement.
Regional Environmental Impact Assessments – A Tool for Improvements and Increased Efficiency in the EIA-Work. Recent experiences from the Norwegian Offshore Activity
Authors: Kinn Sigurd Juel , Strøm Øyvind
Published: December 2007

The Norwegian EIA-system for the petroleum offshore industry has recently been revised based on criticism from several authorities. A revision of the Petroleum Act has made a more flexible system and introduced impact assessments on the regional level based on the existing, planned and expected activity within the region. The main objectives for the revised system are to improve the EIA-work and to make it more efficient.

The paper describes the general EIA-system in Norway for offshore projects and gives an overview of the revised EIA-system which is based on Regional Impact Assessments (REIA) and the Field-specific Environmental Impact Assessments (FEIA). The basic principles in the system and the typical content of a REIA and a FEIA are described.

The Norwegian shelf is divided into 3 main REIA-regions; the North Sea, the Norwegian Sea and the Barents Sea. The current REIA-status in these regions are briefly described. The REIA of the North Sea is recently approved by the authorities and sets a standard for the future REIA-work. The structure and content of this REIA is described more detailed. Further, some of the methods for impact prediction based on the cumulative effect approach are described and the main conclusions in the North Sea REIA are highlighted.

The preliminary experiences with the revised EIA-system regarding the expected improvements and increased efficiency in the EIA-work are finally described. The experiences so far show that it undoubtedly has lead to substansial improvements and indicates that the objective of increased efficiency and overall cost saving in the EIA-work probably will be met.
Fast-track EIA Process for Orenburg Eastern Field Extension, Russia
Authors: Aronson John G. , Raykin Viktor
Published: December 2007

The Orenburg Eastern Field Extension is the subject of a joint-venture oil and gas development project being conducted by JSC STIMUL, with US-based partner Avalon International LLC, Tulsa, Oklahoma. The Orenburg Field is located near the town of Orenburg, Russia, approximately 1300 km SE of Moscow, just north of the Kazakhstan border, and straddling the historic border between Europe and Asia on the Ural River (See Figure 1). The field is one of the oldest and largest oil and gas fields in Russia, with a long history of development in a rich hydrogen sulfide environment. At one point in time, Russia considered evacuating everyone from the area due to the large amount of sour gas (H2S) that was being vented to the atmosphere. Over time, and with careful attention to H2S management, Orenburg has developed substantial oil and gas reserves and a large industrial infrastructure. The JSC STIMUL joint venture applied for support financing from the Overseas Private Investment Corporation (OPIC), thus triggering the need for an Environmental Impact Assessment (EIA). AATA International, Inc. was called upon to perform a fast-track EIA during the winter (January-February 1999), presenting the obvious challenge of not having a full year's field data collection effort. Using a combination of existing historical data, existing Russian EIA (OVOS) and support documents, remote sensing imagery analysis, local participation and consultations, winter field sampling, and rapid turnaround analytical capabilities, AATA was able to produce an approved EIA and Environmental Management Program (EMP) that met OPIC and international standards in a period of just seven weeks from start to finish. Although this type of fast-track process may not be able to be achieved everywhere, the key elements of the fast-track EIA process are identified and discussed, including a) strong local involvement and consultation, b) ability to communicate in the native language, c) understanding of Russian environmental monitoring and modeling, d) advanced remote sensing imagery analysis capabilities, e) state-of-the-art portable field sampling and lab analysis, and f) effective communications with clients, lenders, regulatory agencies, and the public. The fast-track EIA process builds upon concepts advanced by other rapid assessment programs that are gaining in popularity around the world, providing timely information on the key environmental issues associated with project activities. International standards of environmental assessment and performance were achieved through careful enhancement of normal operations conducted within the Russian environmental framework.
The Challenges of Implementing a Common HSE Management System Across a Multiservice, Culturally Diverse International Corporation and Early Results
Authors: Regnault P. , Corrigan M.
Published: December 2007

Since the publication of the OGP (ex-E&P Forum) "Guidelines for the Development and Application of Health, Safety and Environmental Management Systems" in July 1994, HSE Management Systems built along the OGP model have been developed in many sectors of the Oil Industry. Actual field implementation and buy-in from operating units have however been and remain today the most challenging part of the process. This paper shall present the main steps that were followed to successfully implement a common HSE Management System across one multiservice, culturally diverse international corporation and shall review early results.
Can Advances in Drilling Fluid Design Further Reduce the Environmental Effects of Water and Organic-Phase Drilling Fluids?
Authors: Getliff J. M. , Bradbury A. J. , Sawdon C. A. , Candler J. E. , Loklingholm G.
Published: December 2007

Over the years the industry has seen major changes in drilling fluids technology, especially in the field of organic-phase fluids (OPF) such as diesel, mineral oil and synthetic hydrocarbon base fluids. Environmental concerns have driven the development of ‘traditional’ oil-based fluids away from diesel and through to the less toxic, more biodegradable synthetics such as esters and olefins. Many companies are now considering the overall picture regarding the disposal of wastes and are looking for alternative uses for drilling byproducts, thus turning wastes into useful raw commodities.

While organic-phase fluids evolved, research into water- based fluids (WBF), which are generally considered less harmful to the environment, concentrated on duplicating the technical performance of oil-based fluids, the absence of oily discharges being the environmental benefit. A more holistic view of the overall impact of WBF discharges and concerns about the persistence of some WBF chemicals has now focused development on alternative ways to further reduce the impact of water-based fluids on the environment and accelerate recovery of the impacted areas.

The key to reducing the environmental impact of drilling fluids is typified by the standard waste management hierarchy. The areas to consider are source reduction, recycling/re-use of the product, recovery of useful or valuable materials and treatment prior to disposal.

The focus of this paper is how new technologies can be used to bring about these changes and to discuss the various ways in which the amount of drilling fluid by-products can be reduced. The paper also describes ways in which new drilling fluid developments such as salt-free drilling fluids or the use of colloidal weighting agents can be designed to optimize waste management and reduce the amount of waste. These technologies also facilitate the re-use and recycling of drilling fluids and their components.
Cost and Benefit in HSE: A Model for Calculation of Cost-Benefit using Incident Potential
Authors: Hudson P. T. W. , Stephens D.
Published: December 2007

A study is reported in which costs and benefits of safety are studied using three different approaches. Costs were split into Direct costs that arise as a direct result of an accident, Associated costs that arise because an incident is reported, Remedial costs and indirect costs that impact on the company. In an EP company a sample of 70 incidents was studied in detail to arrive at an average cost per incident of £ 14,000 and a platform cost approaching £1m, in close agreement with an earlier study by the UK HSE. An alternative approach, using estimates of likely costs for different types of incidents, arrived at a slightly higher incident cost. Both these approaches use historical events to estimate costs. A third approach, using incident potential, combines costs of possible incidents with associated probabilities of those events to arrive at an expected cost. These expected costs may be expressed in terms of Net Present Value (NPV) to allow a consistent representation of financial and operational risks. On the basis of this study it is clear that level 3 and 4 incidents, minor incidents equivalent to Potential levels 2 and 1 in the Shell Group Risk Assessment Matrix, cost the company in excess of £10m in a year. Indeed, when treated in terms of Net Present Value (NPV) and allowing for undiscovered indirect costs across the company, the risk being carried is probably in excess of £200m.

The effectiveness of remedies and their benefits decay over time. Quick fix remedies lose most of their value within a month, so their benefit measured in NPV is negligible. Effective remedies have long decay rates and learning is well propagated. Safety is seen to pay off when looking at the costs of incidents that have been actively prevented.
Collecting human factors data from accidents and incidents
Authors: Gordon Rachael , Flin Rhona , Mearns Kathryn
Published: December 2007

In order to investigate human and organisational factors in offshore accidents, two human factors incident reporting forms: the Open Reporting Form and the Comprehensive Reporting Form, were developed and evaluated. Using statistical techniques, the form with more structured questions was found to provided 66% more information than the participating company's existing reporting form. The results of the research are described focussing on potential benefits for the offshore oil industry.