bluuebunny/crossref_metadata_2025_split huggingface dataset:
An Analysis of Human Settlement Along the Xan Oil Road in Laguna del Tigre National Park, Guatemala
Authors: Musinsky John N. , Reining Conrad C. S. , Rosenfeld Amy B. , Thomsen Jorgen B. 
Published: December 2007

AbstractA study is made of deforestation rates based on proximity to the Xan oil road in Laguna del Tigre National Park, Petén, Guatemala. Results from a time-series analysis using Landsat Thematic Mapper imagery from 1986 through 1995 and aerial photography from 1997 indicate a high degree of correlation between the oil road and settlement patterns within the national park.
Environmental Risk Assessment - Case Study of an Offshore Petroleum Development
Authors: Pinceratto E. , Casey J. 
Published: December 2007

Abstract
Environmental impact assessment has traditionally been based around a review and assessment of identified impacts and issues. Strategies to mitigate, control and monitor these impacts are also addressed at this stage.
BHP Petroleum has employed a risk based, hazard identification (HAZID) approach at the start of projects to ensure that actual and potential environmental impacts and concerns are identified at the conceptual stage. The benefit of using a HAZID approach is that impacts are identified in a systematic manner through a brainstorming session comprising a multi-disciplinary team. It is at this session that the source of the impacts are identified and methods for their prevention, control and/or mitigation are discussed. An environmental risk matrix has been developed for use in this exercise to prioritise risks in order of their likelihood, and of their impact upon the environment and the Company's business.
This is a valuable exercise which allows the environmental impact assessment process to effectively and comprehensively address all environmental risks. It has the added advantage that it allows all members of a project team to get up to speed with the environmental issues and ensure that methods for prevention and control are addressed during project design. It also takes into account the local environmental sensitivities in all phases of the project, from site selection to construction, operation and decommissioning.
This paper examines this approach in the context of a petroleum development in an offshore marine environment which includes localised complex ecosystems.
Building Consensus for Sustainable Use and Management of Oil Resources
Authors: Tomei Manuela 
Published: December 2007

Abstract
The lands and natural resources in areas inhabited by many indigenous and tribal peoples, especially in Asia and the Amazon countries, are increasingly being prospected and/or exploited by public and private oil and gas companies. Evidence shows that, if not properly handled, this will have severe repercussions on many of those peoples. Livelihood systems can be wiped out, community safety nets dismantled, economic and social infrastructure affected, and kinship ties undermined.
The major challenge is to reconcile the rights and legitimate aspirations of indigenous and tribal peoples with the equally legitimate development needs of the country and the business interests of oil companies. Consultations and negotiations conducted in good faith and through appropriate procedures can help accommodate conflicting interests. This requires an enabling environment, and adequately prepared social parties.
In most cases, however, the institutional capacity to devise, implement and enforce effective environment and social safeguards is terribly weak. Mechanisms for consultation with affected indigenous peoples, prior to and during project execution, tend to be non-existent or inadequate. The principles, requirements, and responsibilities with regard to compensation and rehabilitation schemes, or concerning disputes settlement procedures over compensation or oil operation-related injuries are either lacking or vague. As a result, and because of national and international pressure, several oil companies have adopted measures to minimize social conflicts and adverse social impact. Despite the use of specialized assistance, social issues tend to be beyond the expertise and experience of oil project developers. If and when consultations are conducted, the devised social interventions are generally short-lived and welfare-oriented. Indigenous peoples very often are unaware of their rights, and of relevant provisions under environmental law and/or oil development legislation and regulations. They are equally unequipped to engage in meaningful dialogue and negotiation with oil companies and relevant government agencies. The paper will explore the extent of the problem, outline some of the consequences, discuss a few cases and offer some suggestions
Finding Common Ground for E&P Operations in Indigenous Communities
Authors: Mendez S. , Wasserstrom R. F. , Parnell J. A. 
Published: December 2007

Abstract
In 1994, representatives of ARCO Oriente Inc., the Organization of Indigenous Peoples of Pastaza (OPIP), and Oxfam America began discussions on social and environmental questions arising from the company's proposed development of a major oil field at Villano, Block 10, located in the rainforests of Pastaza Province, Ecuador. Despite considerable complications, ARCO and OPIP forged an innovative agreement that serves as an example of one attempt to move from a culture of confrontation to a culture of dialogue, and to establish appropriate and meaningful parameters for stakeholder participation in E&P projects. The focus of this agreement has been the newly formed "technical environmental committee" or "comité técnico ambiental" (CTA), composed of members from ARCO/Agip, Petroecuador, and three major Indian organizations. This paper describes how this agreement was reached, where it has led since 1994, new issues that have emerged, and whether this committee might offer a model for relations between hydrocarbon companies and native peoples.
Maintaining a Mutually Beneficial Relationship with Host Communities: Our Unique Way
Authors: Ajayi P. A. , Kpiasi E. O. , Wilkie D. 
Published: December 2007

Abstract
Chevron Nigeria operates in the Niger Delta region and has its operational headquarters at the Escravos Terminal which has all the facilities of a small community. One of such facilities is a well-equipped and staffed industrial clinic for the employees. Prior to 1992, this clinic provided emergency health care for the host communities surrounding this terminal because there was no other health facility for them. In 1992, Chevron Nigeria built, commissioned and donated an 18-bed cottage hospital to the host community comprising of about 7 villages and with a population of about 50,000. The community could not run the facility satisfactorily for several reasons and in July 1996, Chevron Nigeria took over the day to day running of the hospital. In the present dispensation, the community provides staff and pays staff salaries and Chevron provides drugs, dressings, hospital equipment, some staff incentives and maintains the facility. Treatment is provided free and no form of identification is required. Since Chevron's intervention, daily attendance jumped from a paltry 4–5 to over 40 and the community is quite satisfied. In the 12 month period between August 1996 and July 1997, total attendance was 14,925.
This paper discusses our mode of operating the facility, community perception, services provided, clinical cases commonly encountered, problems and future plans.
Local Stress Estimates and Far-Field Stress History, Ordos, China
Authors: Luo Y. , Dusseault M.B. 
Published: December 2007

Abstract
Monitoring acoustic emission behaviour during core restressing is a means of collecting stress history information, but this effect (the "kaiser" effect) for rocks cannot he used alone for paleostress reconstruction. Therefore, an integrated approach including regional geological and geophysical information such as magnetic, gravitational, and image data has been implemented in combination with core measurements and imaging logs. This analysis leads to a prohable history of far-field loading, and allows greater confidence in the interpretation in that numerous independent sources seem to suggest that the interpretation is consistent. For details of local stress distributions, Kriging methods are used, based on knowledge of the ancient landforms and erosional geometry. Practical applications of paleostresses in the context of basin analysis seem feasible if fractures can be linked to hydrocarhon migration and accumulation. To demonstrate this, the method is applied in the Ordos Basin in North China to establish the relationships between far-field and local stresses, and to link the stress and fracture history to the migration and accumulation of the large gas field found in the central Ordos area.
P. 527
Reservoir Stress Path: The Depletion and the Rebound
Authors: Santarelli F. J. , Tronvoll J. T. , Svennekjaer M. , Skeie H. , Henriksen R. , Bratli R. K. 
Published: December 2007

Abstract
The paper presents a field case based upon a reservoir operated by Saga Petroleum in the North Sea. The reservoir stress path was determined from a series of minifrac and fall off analyses and step rate tests on various appraisal tests and injection wells. The results show a strong heterogeneity of the stress path with a large difference between the heavily faulted Southern part of the field and the more quiet Central part of it. The stress path was further confirmed by a series of mud loss incidents during drilling that are briefly summarised.
Furthermore, in the case of two injectors, the step rate tests were performed after a significant re-pressurisation of the reservoir -i.e. 30 and 70 bars respectively. Such tests gave extremely low fracturation pressures compared to what was the reservoir stress path upon depressurisation. In fact, the fracturation pressures measured are consistent with the maximum depletion but not the reservoir pressure at the time of the test. In other words, the total minimum stress in the reservoir seems to be governed by the maximum depletion of the zone and not by the present level of pore pressure. Two wells from another North Sea reservoir will also be presented showing a similar behaviour upon repressurisation. Note that such an observation is consistent with one measurement performed on Ekofisk and published earlier on.
These observations of heterogeneous and irreversible stress paths will be analysed and compared to other observations such as the behaviour of surface subsidence during aquifer depletion and repressurisation.
In particular, it is shown that the reservoir stress path is compatible with a rigid plastic behaviour of the rock mass that has already been more or less observed in the case of the Venice subsidence. However, core measurements do not seem to obey such behaviour. The difference can then be attributed to scale effects as the stress measurements via fracturing tests affect large rock volumes.
As a consequence, the results reported here give an insight about what could be the rheological behaviour of a reservoir rock mass at a very large scale. Possible applications to large scale rock mechanics modeling such as compaction, subsidence, hydraulic fracturing, are then highlighted. Finally, the practical consequences of such a state of affairs in terms of reservoir management are drawn.
State-of-the-Art Sand Prediction Based on an Intranet "Push the Button" Interface
Authors: Viken R. , Kjorholt H. 
Published: December 2007

Abstract
Accurate sand prediction in deviated and perforated wells in an anisotropic stress field is not possible with simple analytical models. An advanced finite element model (FE model) has the capability to simulate any geometry and nearly any material behavior, but has, due to its complexity, in the past only been applied by a few specialists. By adding a user-friendly interface based on Internet technology, and letting the user select from a collection of predefined FE models, the user is now able to perform advanced sand prediction simulations from a WEB page. The user is required to specify formation properties, rock stresses, reservoir and well pressures and completion geometry as input parameters. From this input and a library of FE meshes, the simulator generates the finite element model and starts the simulation. The results are presented to the user in a WEB page. The results are presented in a standard and consistent way, which ensures good quality control in the interpretation of the results. By using this sand prediction simulator, complex modeling of the sand production potential is now available for all production engineers involved in well completion design in Statoil.
P. 271
Compressional Wave An Isotropy Caused by Single and Multiple Fractures
Authors: Pyrak-Nolte Laura J. , Shiau Jing-Yen 
Published: December 2007

Abstract
Compressional wave anisotropy caused by a single fracture and three parallel fractures was measured using an acoustic imaging system. The measured compressional wave transmission coefficients are compared with theoretically predicted transmission coefficients from the displacement discontinuity theory. Deviations from the displacement discontinuity theory occur at glancing angles of incidence to the fracture. The anisotropy in the transmission coefficient is observed to be frequency dependent and results in an apparent frequency-dependent stiffness.
P. 299
Compaction in Soft Weak Rocks Due to Water Flooding
Authors: Papamichos E. , Brignoli M. , Schei G. 
Published: December 2007

Abstract
The mechanical behavior of some Adriatic soft weak reservoir rocks obtained from cores is characterized taking into account water saturation effects. The characterization includes triaxial compression, and uniaxial strain (oedometric) tests, as well as water injection tests under reservoir conditions. From the experimental results, a uniaxial strain compaction model for weak rocks is calibrated for use in reservoir compaction studies in the Adriatic Sea area. A porosity-dependent elastoplastic model is used to capture the variation of compaction in the materials in the reservoir zone.
P. 411
A Comparison of Deterministic and Reliability-Based Design Methodologies for Production Tubing
Authors: Raney James B. , (Suri) Suryanarayana P. V. R. , Maes Marc A. 
Published: December 2007

Abstract
In this paper, we compare reliability-based procedures for design of production tubing with the traditional working-stress design method. The basic approach of Working Stress Design (WSD), Load and Resistance Factor Design (LRFD) and Quantitative Risk Assessment (QRA) are discussed. Load and resistance methodologies for the three approaches, and their impact on the tubing design are contrasted. The relationship between the Safety Factor (SF) used in WSD, the Load Factors (Lf) and Resistance Factors (Rf) used in LRFD, and uncertainity propragation used in QRA is illustrated. These relationships are then compared and contrasted with the determined reliability for a given design. A few illustrative examples are provided for the three different design methods. Graphs illustrating the relationship between SF and estimated design reliability allow a reliability-based interpretation of WSD, and give insight into the design reliabilities implicit in WSD. By means of such a comparison to a familiar design format, this paper aims to give the reader an understanding of, and confidence in LRFD/QRA format for the design of production tubing. The tendency of WSD to overdesign tubing from a reliability stand-point is illustrated. It is concluded that while QRA is the best approach to designing production tubing to a desired reliability, LRFD allows reliability-based design in a format that is relatively easy to apply.
Analytical Burst Strength Prediction of OCTG with and without Defects
Authors: Klever F. J. , Stewart G. 
Published: December 2007

ABSTRACT
Casing and tubing are generally designed against burst by requiring a safety margin between the calculated stresses and the yield strength of the material. This same formula is then often used to determine the remaining burst strength of casing that suffered from drillstring wear or wireline wear, in the latter case sometimes including an additional penalty to account for stress concentrations. This approach is very conservative and, moreover, leads to actual safety margins against burst that vary widely over different grades.
Improved and novel approaches towards tubular design and fitness-for-purpose call for models that can accurately predict failure as opposed to conservative assessment procedures. Much progress has been made in developing verified burst strength models for ‘regular’ pipe, accounting for the acceptable wall thickness variability. In this paper attention is paid to pipes with cracks, but the main focus is on the accurate quantification of the degradation of the burst strength due to longitudinal wear.
Burst tests have been carried out on a number of pipe specimens with a wear groove machined at the inside; some of these with axial cracks at the outside. Also finite-element analyses have been performed, simulating the burst of these pipes and also others from different grades and sizes, with defects of different depths and shapes ranging from drillstring wear and wireline wear to sharp cracks.
By combining the results of the tests and the analyses, a simple analytical burst model has been developed that shows an excellent performance for regular pipe and worn pipe. The equations developed here are also applicable to describe the limit behaviour of pipes with crack-like defects, provided ductile tearing is taken into consideration and fracture instability does not occur. More details on the approach to account for flaws in the burst strength of OCTG is presented in a companion paper by Stewart and Klever [1].
This work is directly applicable in the design and fitness-for-purpose analysis of casing and tubing.
Improved Production Log Interpretation in Horizontal Wells Using a Combination of Pulsed Neutron Logs, Quantitative Temperature Log Analysis, Time Lapse LWD Resistivity Logs and Borehole Gravity
Authors: Brady J. L. , Watson B. A. , Warner D. W. , North R. J. , Sommer D. M. , Colson J. L. , Kleinberg R. L. , Wolcott D. S. , Sezginer A. 
Published: December 2007

Abstract
A novel combination of logs and their unique interpretations are used to improve the understanding of production in horizontal wells on the North Slope of Alaska. Two techniques using Pulse Neutron Capture (PNC) logs to identify and quantify liquid productive intervals were previously presented in a paper by Brady et. al1. These techniques are compared and combined with two additional techniques: 1) the use of time lapse LWD resistivity to determine productive intervals and liquid flow profiles while drilling, and 2) a non trial-and-error method to determine quantitative gas production using temperature logs in a two-phase flow. Finally, modeling shows borehole gravity logs can be used to track the vertical movement of gas or water tens of feet above or below horizontal wells.
Integrating the time lapse differences between shallow LWD resistivity logs run while drilling and logs run several hours after drilling show a strong correlation with PNC liquid flow profiles for wells producing at solution GOR. Additionally, combining a quantitative gas flow rate analysis from the temperature log with the liquid profile provides a complete analysis of the production profile for two-phase flow in horizontal wells. Finally by combining the production profile analysis from a horizontal well with the modeled timelapse borehole gravity data, a complete understanding of the fluid movements in the well borehole and up to two hundred feet into the formation can be obtained.
These techniques can be applied to both horizontal and vertical wells with both slotted liner and cemented perforated completions to obtain a quantitative production profile. The LWD resistivity data, collected while drilling, provides an indication of the productive reservoir rock before the well is completed. Time lapse borehole gravity provides an understanding of the reservoir fluid movements affecting the wellbore flow profiles after the well has been put on production.
Heavy Oil Production from Unconsolidated Sandstones using Sand Production and SAGD
Authors: Dusseault Maurice B. , Geilikman Mikhail B. , Dusseault T. J. T. (Tim) 
Published: December 2007

Abstract
Three major new technologies developed in the past decade in the heavy oil regions of Alberta and Saskatchewan are long, shallow horizontal wells, Steam-Assisted Gravity Drainage (SAGD), and Cold Production (CP). These three technologies are briefly reviewed. They can be combined in a general approach to heavy oil reservoir development that will give the advantages of reasonable early oil production rates, continued long-term production, and excellent long-term recovery.
A combination of vertical wells and horizontal wells are used to achieve early CP, which is then gradually replaced by long-term SAGD production. As the processes progress, vertical CP wells will decline in production rate; when they are no longer economical to produce, these wells are converted to other purposes. They can be used as inert gas injectors, control wells, low-rate thermal injection or production wells, or even sand disposal wells, as long as they help maintain the reservoir at the appropriate pressure for SAGD. The proper balance of pressures through injection or production to maintain the long-term stability of processes in the gravity-dominated flow regime is critical to SAGD success.
Given price fluctuations and long-term projections, economic factors related to heavy oil must be addressed. It is appropriate to point out that within 10-15 years, the current conditions of low prices and over-supply of conventional crude oil will be replaced by a world-wide shortfall in oil supply, which should bring a permanent increase in oil prices.
This suggests that corporations should be making substantial investments in heavy oil at the present time.
Effects of Single and / or Combined Application of Water and Oil Based Drill Cuttings in a Tropical Agricultural Soil Located in JusepíN Oil Field (Monagas State, Venezuela)
Authors: Caraballo Luis , Urich Juan , Vásquez Pedro , Marcano Pedro , Muzziotti Reinaldo , Rodríquez Alberto , López Carlina , Marcano José , Rodríquez Pedro , Colombo Pedro , Quiñones Rubén , Asuaje Ramón 
Published: December 2007

Abstract
At eastern Venezuela, the oil developments are established mainly in areas with agricultural and cattle rising activities. This compel to an effective and environmentally safe treatment for water (WB) and oil based (OB) drill cuttings (DC), according to the Venezuelan regulations. In order to determine the effects of individual and combined applications of WB and OB in an acid soil (Ultisol), it was designed and installed on January 1997 a field test in the Jusepín Oil Field (Monagas State). In 9 plots of 0.7 ha. each one, were applied the following treatments (equivalent doses in m3/ha.): WB: 0, 125, 250, 500; WB/OB: 90/72; 180/140, 360/280; and OB: 100, 200, 400. Then were applied an adjusted fertilization (N, P, S), complementary amendments and periodical tillage, to stimulate the hydrocarbons biodegradation (TPH). After a 87 days period, the TPH percentage in OB treatments (45.9 %) was smaller than WB/OB (53.3%). Due to the use of CaO at the output of solids control equipment as dryer for DC, some soils plots showed high Ca++ and pH, mainly at high DC doses (an over liming effect). Other soil and leacheates parameters (electric conductivity, Cl-, TPH and heavy metals), were found under the established limits by ad hoc environmental regulation (actually being reviewed). The 500 WB treatment shown both, high soil fertility and grasses growth. The results shown that is feasible the WB/OB application, being reduced the treatment area for the safe disposal of more than 2000 m3 DC by well