bluuebunny/crossref_metadata_2025_split huggingface dataset:
Development and Implementation of an Environmental Management System for an Oil Company in South Trinidad in Accordance with the ISO 14001 Standard
Authors: Ramnath K. , Dyal S. , Seeram B. , Maharaj P. 
Published: December 2007

Abstract
Trinidad and Tobago has the oldest petroleum industry in the world. The activities of this industry have historically impacted the environment and newly drafted environmental rules and regulations of Trinidad and Tobago will require sound environmental management systems by all operating companies in the industry.
In order to meet the challenges of these new regulations, the Petroleum Company of Trinidad and Tobago Limited (Petrotrin) is currently pursuing the development and implementation of an Environmental Management System within its Exploration and Production operations in accordance with the ISO 14001 Standard. This project was initiated in October 1999, and is expected to terminate in December 2001 with international certification.
Petrotrin, realizing the competitive advantages that can result from the integration of an Environmental Management System into its operating systems, has placed the implementation of the EMS as a company strategic goal.
The project was categorized into three main stages: Development, Implementation and Audit/Certification. To date, the Development Stage has been completed and the implementation stage initiated, with the following successes: Allocation of manpower resources in the formation of the Steering and Executive Management Committees, and an EMS Project Team;Training of project personnel in ISO 14001/10/11/12 Standards;Revision of the company Environmental Policy statement;Conducting the Gap Analysis Study;Development of the Implementation Plan based on the results of the Gap Analysis;Initiated the development of the EMS manual and drafted initial procedures as outlined in the Implementation Plan;Collection and analysis of data for identification of Significant Environmental Aspects and impacts for Exploration and Production activities.
The Development and Implementation of an Environmental Management System in accordance with the world renowned ISO 14001 is expected to derive many benefits to Petrotrin such as reduced operating costs, improved financial performance, increased access to markets, improved environmental performance, improved community relations, improved customer relations and employee involvement and education.
Development of Fractured Reservoirs of the Mulichinco Formation Using 3D Structural Modeling: Filo Morado Field, Neuquén Basin, Argentina
Authors: Zapata Tomás , Olivieri Gustavo , Dzelalija Francisco 
Published: December 2007

Abstract
The Filo Morado field produces hydrocarbons from primary porosity and fractured reservoirs such as the Mulichinco Fm., a fine grained calcareous sandstone and sandy limestone with 4 to 6% primary porosity. This unit has been developed as a conventional reservoir; most of the wells resulted dry or with a very low accumulated production. New 3D seismic information is scarce and highly laterally displaced due to the structural and geological complexities. 3D geologic modeling was made from twelve 2D structural sections. The different horizons were connected to generate a 3D solid model, with different velocity layers to perform a depth migration of the seismic data. The corrected seismic data allowed to characterize the 3D geometrical distribution of the faults and geological data. 3D structural analysis, combined with surface and depth data (logs, cores, well cutting, etc.) made possible to propose a kinematic model as a doubling detachment east-directed fold combined with backthrusting that tilted and displaced the flat crest to the west. Fracture geometry was inferred from core analysis, borehole images and outcrops. Fracture genesis may be related to flexural slip and to accommodation zones and to the regional stress field after the folding mechanism was locked. A development well was drilled to structurally evaluate the different segments of the structure. Drilling results as well as production data suggest that the forelimb environment is highly fractured; in accordance with the model predictions.
Maximization of a Field Characterization Using 3D Seismic: Case Study, C-2 Reservoir, Block VIII, Occidental Basin, Lake Maracaibo, Venezuela
Authors: Carrizales R. , Sifonte E. , Aguilar T. 
Published: December 2007

Abstract
In this work a methodology is developed in which is applied the advances of applications of seismic 3D (Variance Cube, Seismic Attributes, Three Dimensional Visualization, incorporating Well/Seismic depth cross sections, and others) in the evaluation of the field, integrating it with the disciplines of the geosciences to obtain a static model of the producing reservoir. This study is of great help in the reevaluation and interpretation of areas currently producing and also gives better definition and characterization of remaining prospective reservoir areas.
The study area is from the middle portion of Lake Maracaibo, Western Basin of Venezuela, more specifically in the Seismic 3D cube of Block VIII. The dataset cube embraces an area of 265 Km2; comprised by approximately 700 Inlines and 1400 Crosslines. Later in the project the study was further detailed in a smaller cube of 112 Km2 in order to study the C-2 reservoir of Block VIII. In total there were 152 wells loaded in the database.
Within the regional stratigraphic column, there were interpreted four (04) Seismic reflectors range from the Cretaceous period into the Miocene, and these reflectors show strong acoustic impedance and are of great areal extension, which are: Socuy member of the Creatceous Colon Formation, Guasare Formation(Paleocene), Top of Eocene Uncomformity and the Rosa Formation (Miocene). Subsequently the C-2 and C-3 Sands of the Eocene Misoa formation were interpreted in VIII Block.
The objective is to study the C-2 Sand of Block VIII which contains 190.7 MMBLs POES (original oil in place), remaining oil in place of 11.7 MMBLs, and accumulated production of 33.4 MMBLs with an oil retrieval factor of 23.65 % and oil of gravity of 27.5° API. This sand is segregated into six (6) separate reservoirs in this block.
The application of this methodology helped in finding new develoment prospects and increased the net recoverable barrells in the area of study.
Evaluation of the Dispersion Model in a Refinery, Lujan De Cuyo
Authors: Correa G. , Fernandez L. , Vera F. 
Published: December 2007

Abstract
Environmental Management System faced by Repsol YPF has implicating the installation of dispersion models of pollutants in the industrial pole of Mendoza. For this utilization with more complex objectives (for example: environmental impact studies, comparison with procedures of quality of the air, etc.) is necessary to confirm the predictive capacity of the model. The used method was to compare the results of model with monitoring data during the same period. It must be emphasized that the credibility of the confirmation requires a top quality in all the data used in the comparison, that is to say in monitoring data, emission and meteorology. The duration of the evaluation of the model was for a year.
Waterflooding Optimization Using Biotechnology: 2-Year Field Test, La Ventana Field, Argentina
Authors: Maure Alejandro , Dietrich Forrest , Gomez Ulises , Vallesi Javier , Irusta Marcelo 
Published: December 2007

Abstract
Biotechnology improved water flood performance during a two-year test in Victor Claro reservoir layers C2-D2, La Ventana field, northern Cuyo Basin, Mendoza Province, Argentina (Figure 1, 2 and 3). Paraffinic oil has been produced by water flooding since 1989. The objective of this project was to determine the technical and economical feasibility of Microbial Enhanced Oil Recovery (MEOR) methods for field-wide application in mature water floods. This paper explains the continuation of a pilot study of controlled microbial colonization in producer wells begun in La Ventana field in 1995.
Fluid property alterations were evaluated using a complete set of rheology parameters, specific geochemical fingerprints and bioassays on more than 82 samples from La Ventana and neighboring fields. The oil proved to be highly bio-treatable and formation water to be compatible with MEOR requirements. Reservoir conditions, including rock properties, pressure and temperature were also favorable.
Microbial Inoculation Program started December 1998 and was implemented by systematic treatment of injected water using hydrocarbon degrading anaerobic-facultative microorganisms on a non-regular injection pattern having direct influence on four neighboring producers (Figure 4). A complementary tracer field test using Tritium permitted validation of inter-well connectivity and allocation factors initially inferred by the use of streamline simulation. Pre-MEOR and Post-MEOR fractional flow field performance in producers was also correlated with theoretical predictions using a proprietary 2D, vertically integrated streamline simulator. The tracer and simulations contributed to better understanding MEOR mechanisms and to better designs for bio-treatments.
Original oil production decline rates improved. Increments in oil cut were measured using conventional methods for 24 months after MEOR program started (Figure 19). Two combined mechanisms help explain the change: Further depletion of residual oil saturation by in-situ production of metabolites with low interfacial tension andImproved oil mobility from short-chain solvents originated by microbial alteration of heavy paraffinic ends.
Further evaluations will cover extension of pilot period and economic feasibility analysis for large-scale MEOR implementation in other zones under conventional flooding.
SAGD Performance Optimization Through Numerical Simulations: Methodology and Field Case Example
Authors: Egermann P. , Renard G. , Delamaide E. 
Published: December 2007

Abstract
SAGD is a very promising recovery process to produce heavy oils and bitumen resources. The method ensures both a stable displacement of steam and economical rates by using gravity as the driving force and a pair of horizontal wells for injection/production. After several years of small scale field tests (pilots), the method is now considered as mature and large scale projects are scheduled in a near future (in Canada for instance). Nevertheless, both technical and economical success of the process require a satisfactory development of the steam chamber, which can be achieved by well monitoring (i.e. steam trap control).
This paper presents a general methodology based on numerical investigations to obtain and maintain an optimized development of the chamber throughout the production life of the wellpair. First, the methodology is explained on a synthetic case and applied to a real field case example. Field data are first history matched with the model and then the proposed approach is used to evaluate how the oil production could have been enhanced and optimized further.
It is shown that an optimized steam chamber development is obtained by adjusting the steam injection rate to the potential of the reservoir (fluids and geology) and by monitoring the production rate during the process/operations to keep the steam chamber as large as possible but away enough from the production well to prevent any steam breakthrough. The results are in good agreement compared with Butler's analytical model (oil rate and steam chamber shape). A very good history match is obtained in the field case example. The proposed methodology shows that oil production rate can be doubled when injection/production rates are adapted to the SAGD reservoir potential.
Reservoir Characterization of the Orinoco Heavy Oil Belt: Miocene Oficina Formation, Zuata Field, Eastern Venezuela Basin
Authors: Kopper Robert , Kupecz Julie , Curtis Carl , Cole Tony , Dorn-López Donald , Copley Jeffrey , Muñoz Alberto , Caicedo Vladimir 
Published: December 2007

Abstract
The Zuata Field, located on the southern flank of the Eastern Venezuela Basin, produces heavy oil from porous unconsolidated sandstones of the Lower Miocene Oficina Formation. The Oficina Formation is composed of multiple depositional sequences which display complex erosional geometries. This creates an intricate reservoir architecture as younger fluvial systems down-cut, erode and re-distribute the sediments of earlier-deposited systems within each depositional sequence. Superimposed on this intra-sequence complexity is the downcutting and interconnection of sands of different depositional sequences.
The Oficina Formation within the study area can be subdivided into eleven depositional sequences. Each depositional sequence has been characterized in terms of environments of deposition and mapped, which has allowed visualization through time of the facies and reservoir geometries. Within sequences, environments of deposition include a mix of fluvial, distributary channel, estuarine, tidal channel, delta plain and coastal plain, resulting in variable net to gross ratios and variable kv/kh. Productive sands are located within incised valleys, usually within the basal part of each depositional sequence, while sediments in the inter-valley areas comprise a combination of older (pre-incision) deposits and thin delta plain / coastal plain deposits. These are variously intercalated siltstones, fine-grained sandstones and coals, and are generally non-productive.
Enhancing Steamflood Effectiveness by Horizontal Producers
Authors: Leonhardt Bernd 
Published: December 2007

Abstract
The Emlichheim oilfield is located in North-West-Germany on the Dutch-German border being the Southern downdip part of the Schoonebeek anticline. The field was discovered in 1943 and came on production in 1944. Since production startup, Wintershall operates the field as owner of the concession (90 % share of interest) in a joint venture with Mobil Erdgas-Erdoel GmbH (10 %).
For more than 50 years an average crude oil production of 150,000 tons/yr (1.05 MMstb/yr) has been maintained. Starting with huff ‘n’ puff and hot water flooding in the late 60's, the first steam flood project was implemented in 1981. Further steamflood projects started in 1989, 1992, 1993, 1994 and 1998 in different areas of the field. Until 1997, only vertical production wells were drilled in the field. Wellbore stability seemed to be a major problem for drilling horizontal wells in the unconsolidated sandstone reservoir at that time.
In 1999 an innovative steamflood project was started with three newly drilled horizontal producers surrounding a vertical steam injector. First results are showing a significant improvement in the performance as compared to the earlier projects and offer new chances for further development of the field. Today, the field could no longer be operated without the steam projects as roughly 95 % of the field production is coming from thermal EOR.
This paper gives a brief overview of the field and its production history, the planning and realization of a current steamflood project using horizontal well technology as well as its performance compared to the earlier projects. It also describes the experience of drilling horizontal wells in the unconsolidated sandstone. A brief outlook to the future field development is given.
Experiences Using an ESP Application on Heavy-Oil Cold-Production Automation in Eastern Venezuela Fields
Authors: Aponte H. , Toussaint L. , Ramos M. 
Published: December 2007

Abstract
PDVSA Automation Strategy for Electro-Submersible Pump artificial lifting of heavy and extra-heavy crude is inspired on the reality of subsurface conditions and successful experiences from applying ESP methods. The usage of pure thermal and heating methods to manage crude viscosity is constrained due to the risks it represents in damaging the pump-motor arrangement. On the other hand, the advantages of using the heating effects of the motor, combined with the injection of light crude as a dilute fluid, both subsurface and surface to decrease crude viscosity, have given great results when incorporating subsurface and surface automation strategies.
The benefits resulting from the use of an integrated strategy, is a consequence of maintaining production rates constant, regardless of day and night viscosity variations and other changing conditions from changes in the process behavior. Additionally, a less hostile operating environment results in a longer lifetime of the motor-pump arrangement. A case study considering the controllability of the ESP system running in a heavy and extra-heavy cold production environment is presented.
Promising Progress in Field Application of Reservoir Electrical Heating Methods
Authors: Sierra R. , Tripathy B. , Bridges J. E. , Ali S. M. Farouq 
Published: December 2007

Abstract
Electrical Heating of heavy oil reservoirs has been successfully applied in near wellbore regions. Well stimulations through downhole resistive, dielectric, or induction electric heating systems when applied in suitable reservoirs can triple flow rates for a small additional operating cost. In such cases high-energy conversion ratios such as 10-15 bbls. Of oil for every bbl of oil consumed at the power plant can be achieved. Applications of electric heating can particularly be beneficial in situations where steam cannot be used due to either depth, formation incompatibility, low incipient injectivity, excessive heat losses or existence of thief zones. Additionally, for reservoirs already having a high temperature in the 60-80 degree C and higher range, only a small amount of electric heating-stimulation is enough to increase oil production by an order of magnitude. Some Orinoco reservoirs of Venezuela fall into this category. Heavy oil reservoirs, overlain by heat sensitive permafrost, may also find electrical heating a viable thermal stimulation technique. Electrical heating process has also been adapted to apply in preheat phase of other complimentary processes like VAPEX. The process also has been investigated for hot water flood in deep reservoirs. This paper proposes to use downhole electric systems for stimulating for both vertical and horizontal wells in such reservoirs. Using CMG's thermal simulator-STARS (ref. 7), results of several worldwide investigations are included. A summary of field applications is also presented. In addition, incremental oil recovery vs. energy consumption is tabulated.
Helitherm-Solar Power Throughput Enhancement and Heat Tracing for Heavy Oil Pipelines
Authors: Lasich John , Kaila Neelabh 
Published: December 2007

Abstract
Helitherm is a passive and stand-alone solar thermal powered heating system for pipelines and vessels and is applicable for crude oil/product flow enhancement and heat tracing in above-ground installations.
Helitherm's operating principle relies upon an integrated thermal diode, which traps sunlight and retains heat. The pipeline is fully insulated and therefore heat loss is minimized and the elevated temperature maintained.
This paper specifically addresses the throughput enhancement of heavy crude oils using Helitherm technology. In order to quantify the throughput enhancement, Solar Systems has developed a computer model called Helitherm Dynamic Simulator to evaluate the pressure drop and temperature profile of a Helitherm pipeline and compare it with a bare pipeline under average sunshine conditions. This program can also be used for nighttime analysis of pressure drop and temperature profile in Helitherm and bare pipelines. This program evaluates the pressure drop at crude oil viscosity corresponding to an integrated average pipeline temperature. FEA techniques are also being developed to obtain a more accurate pressure and temperature profile.
Based on this computer model, Solar Systems has conducted several feasibility studies for oil companies around the world. Two studies, one for Petroleos de Venezuela SA and the other for Pertamina (Indonesian National Oil Company) have been discussed in detail.
For PDVSA, the existing throughput of 231BOPD will increase to 306 BOPD, resulting in a percentage increase of 32.4%.
Similarly for Pertamina the increase in throughput is from 386.4 BOPD to 452.4 BOPD, resulting in a percentage increase of 16.8%. The payback period for both projects is less than one year.
In addition to the increase in throughput under no flow (stagnation) conditions, the pipelines are maintained at a temperature higher than the pour point at all times. This eliminates the pipeline start-up problems.
Another version of the computer program (called Helitherm Static Simulator), which predicts the temperature profile of a solar heated pipeline during no flow (stagnation) conditions has been developed and validated for a range of climatic conditions.
Solar Systems Pty Ltd has analyzed the Thayfut pipeline for Petroleum Development of Oman to demonstrate the capability of Helitherm as a stand-alone heat tracing system.
Both these programs would assist a pipeline designer in evaluating the pressure drop, pipe sizing, selection of pumps, investigating pipeline start-up problems and computation of thermal expansion in pipelines.
Helitherm technology is an innovative and economically attractive alternative to the conventional electric or steam heat tracing of pipelines or utilization of drag reducing agents (DRA's) or pour point depressants.
Depending upon process requirements, this technology is specifically suited for tropical and mid latitudes. This technology is also suitable for vessels.
Application of Advanced Heavy-Oil-Production Technologies in the Orinoco Heavy-Oil-Belt, Venezuela
Authors: Robles Jorge 
Published: December 2007

Abstract
The successful application of state of the art drilling technologies such as horizontal and multilateral wells for the development of Zuata field in the Orinoco Belt demands improvements in the areas of artificial lift, fluid gathering and fluid treatment. The economic production of wells with initial potentials beyond 3,000 nbpd challenges both equipment and process.
This paper summarizes the latest experiences of Petrozuata C.A. in the Zuata field in the use of electric submersible pumps, and progressive cavity pumps, as well as the application of state of the art instrumentation for monitoring of production parameters.
Success Of Water-Alternating-Steam-Process for Heavy Oil Recovery
Authors: Ramlal V. , Singh K. Sono 
Published: December 2007

ABSTRACT
The recent period of depressed oil prices which reached as low as $US 5.97/bbl for heavy oil drove major reviews in heavy oil recovery economics, and led to a substantial shift in the operation of four (4) of Petrotrin's thermal projects. The shift was predicated upon key factors such as: experience derived from the North Fyzabad project, a mature steamflood which was converted to a heat scavenging project in 1996the need to assure project viability by maintaining a reasonable lifting cost.at least sustain the present level of decline rates associated with each project.
In February 1999, North Palo Seco, Apex Quarry and Bennett Village, three (3) mature thermal projects at Petrotrin were placed on the water-alternating-steam-process (WASP) and another, Central Los Bajos was converted in August 1999. The four (4) projects are in close proximity each exploiting the Lower Morne L'enfer sandstone and their operating and reservoir characteristics are quite similar. In two (2) of the schemes, selected patterns were converted to WASP, the other patterns being kept on continuous steam. The criteria for pattern selection were pattern temperature, steam-oil-ratio, produced WOR, susceptibility to steam breakouts, and minimal alteration to main piping system.
The paper discusses capital expenditure for the conversion which was kept to an absolute minimum, operating cost which was subsequently reduced; profitability which increased; reservoir response to water injection which resulted in an increase in oil production rate and problems associated with implementation. The paper also discusses techniques of day-to-day flood monitoring, highlights operational problems and presents future operating strategies.