The document discusses Santos Basin development plans from 2012-2016 and through a 2020 strategic plan. It summarizes that the company plans to develop 38 new production systems through 2020, with 25 located in the Santos Basin and 24 in the pre-salt area. It presents charts showing Brazil's projected oil and natural gas production curves from 2017-2020, with production expected to increase through development of pre-salt reservoirs and new discoveries.
Well log interpretation involves using well log data to estimate reservoir properties. It has been used since the 1920s to qualitatively identify hydrocarbons and is now a quantitative tool. A key figure was Gustavus Archie who in the 1940s established the field of petrophysics by relating well logs to core data. His work allowed properties like porosity, permeability and fluid saturation to be estimated. A presentation on well log interpretation outlined the workflow including editing logs, estimating properties like shale volume, porosity, permeability and fluid saturation, and presented two case studies analyzing different carbonate reservoirs.
Well lod ,well Testing and mud logging Ghulam Abbas AbbasiUniversity of Sindh
Well logging records measurements made in boreholes to characterize underground formations. Key logs described include gamma ray, which measures natural radioactivity to identify shale; spontaneous potential, which indicates lithology; caliper, which measures borehole size; resistivity, which distinguishes water and hydrocarbon zones; and neutron, which determines porosity. Mud logging continuously monitors drilling mud and cuttings for gas readings. Well testing evaluates reservoir properties through daily tests and drill stem tests to determine flow rates and commercial potential.
Reservoir rocks experience compaction when fluid is produced, causing a change in pore volume and effective stress. There are three types of compressibility - rock matrix (grain) compressibility measures change in grain volume, rock bulk compressibility measures change in total formation volume, and pore volume compressibility measures change in pore space. Accurately measuring and modeling compressibility is important for predicting changes in porosity and formation properties during production.
This document provides information on estimating oil and gas reserves. It defines various classifications of reserves from proven to unproven, and how reserves are estimated using volumetric, material balance, and production performance methods. The key classifications discussed are proven and probable reserves, with proven reserves having a 90% certainty of recovery and probable having 50% certainty. Volumetric estimation calculates initial hydrocarbon volumes using parameters like rock volume, porosity, fluid properties, and recovery factors.
Porosity Permeability Relationship in carbonate rock pptAmar Gaikwad
A information about porosity and permeability in a carbonate rock. in which we studied the porosity measurement , carbonate rock ,permeability and correlation between them.
1. The document discusses spontaneous potential (SP) logging, which measures the electrical potential difference between a downhole electrode and a surface reference electrode. SP logs can be used both qualitatively to detect permeable beds and quantitatively to determine formation water resistivity and shale volume.
2. The key factors that affect the SP response are the ratio between mud filtrate resistivity (Rmf) and formation water resistivity (Rw), as well as bed thickness, resistivity, and porosity. Positive deflections occur when Rmf > Rw and negative deflections when Rmf < Rw. No deflection occurs when Rmf = Rw.
3. Examples are given of how to calculate shale
Play-Based Exploration (PBE) has become a trendy term in the oil and gas industry, championed by companies like ExxonMobil, Shell and BP.
PBE methods vary significantly; some firms create ‘traffic light’ maps of overall relative profitability, others partitioning probability into play/shared and local /prospect-specific probability with assigned values.
Play-based exploration reflect a shift in focus, as prospects are not the basic unit of exploration, but plays are.
Individual prospect probabilities are balanced and calibrated with the play maps, and prospect volumes are validated against the field size distribution (FSD) for the play.
Exploration evaluation experts use play-based exploration (PBE) to build a full understanding of the geological basins that should be explored and to reassess exploration strategies.
A detailed explanation for one of the most substantial tools in the wire-line formation testers family including the history of wire-line formation testers family, the main functions of the tool , the difference between RFT and DST , the operation of the tool , the pressure profiles , log presentation , log interpretation , corrections with other tools and permeability calculations from pressure measured by the RFT tool.
Well log interpretation involves using well log data to estimate reservoir properties. It has been used since the 1920s to qualitatively identify hydrocarbons and is now a quantitative tool. A key figure was Gustavus Archie who in the 1940s established the field of petrophysics by relating well logs to core data. His work allowed properties like porosity, permeability and fluid saturation to be estimated. A presentation on well log interpretation outlined the workflow including editing logs, estimating properties like shale volume, porosity, permeability and fluid saturation, and presented two case studies analyzing different carbonate reservoirs.
Well lod ,well Testing and mud logging Ghulam Abbas AbbasiUniversity of Sindh
Well logging records measurements made in boreholes to characterize underground formations. Key logs described include gamma ray, which measures natural radioactivity to identify shale; spontaneous potential, which indicates lithology; caliper, which measures borehole size; resistivity, which distinguishes water and hydrocarbon zones; and neutron, which determines porosity. Mud logging continuously monitors drilling mud and cuttings for gas readings. Well testing evaluates reservoir properties through daily tests and drill stem tests to determine flow rates and commercial potential.
Reservoir rocks experience compaction when fluid is produced, causing a change in pore volume and effective stress. There are three types of compressibility - rock matrix (grain) compressibility measures change in grain volume, rock bulk compressibility measures change in total formation volume, and pore volume compressibility measures change in pore space. Accurately measuring and modeling compressibility is important for predicting changes in porosity and formation properties during production.
This document provides information on estimating oil and gas reserves. It defines various classifications of reserves from proven to unproven, and how reserves are estimated using volumetric, material balance, and production performance methods. The key classifications discussed are proven and probable reserves, with proven reserves having a 90% certainty of recovery and probable having 50% certainty. Volumetric estimation calculates initial hydrocarbon volumes using parameters like rock volume, porosity, fluid properties, and recovery factors.
Porosity Permeability Relationship in carbonate rock pptAmar Gaikwad
A information about porosity and permeability in a carbonate rock. in which we studied the porosity measurement , carbonate rock ,permeability and correlation between them.
1. The document discusses spontaneous potential (SP) logging, which measures the electrical potential difference between a downhole electrode and a surface reference electrode. SP logs can be used both qualitatively to detect permeable beds and quantitatively to determine formation water resistivity and shale volume.
2. The key factors that affect the SP response are the ratio between mud filtrate resistivity (Rmf) and formation water resistivity (Rw), as well as bed thickness, resistivity, and porosity. Positive deflections occur when Rmf > Rw and negative deflections when Rmf < Rw. No deflection occurs when Rmf = Rw.
3. Examples are given of how to calculate shale
Play-Based Exploration (PBE) has become a trendy term in the oil and gas industry, championed by companies like ExxonMobil, Shell and BP.
PBE methods vary significantly; some firms create ‘traffic light’ maps of overall relative profitability, others partitioning probability into play/shared and local /prospect-specific probability with assigned values.
Play-based exploration reflect a shift in focus, as prospects are not the basic unit of exploration, but plays are.
Individual prospect probabilities are balanced and calibrated with the play maps, and prospect volumes are validated against the field size distribution (FSD) for the play.
Exploration evaluation experts use play-based exploration (PBE) to build a full understanding of the geological basins that should be explored and to reassess exploration strategies.
A detailed explanation for one of the most substantial tools in the wire-line formation testers family including the history of wire-line formation testers family, the main functions of the tool , the difference between RFT and DST , the operation of the tool , the pressure profiles , log presentation , log interpretation , corrections with other tools and permeability calculations from pressure measured by the RFT tool.
The document discusses the classification of well logs. It explains that logs can be classified based on their technology (open hole vs cased hole logs) or their function (lithology, electrical, porosity, nuclear logs). Open hole logs are run before casing while cased hole logs are done after casing through the metal piping. Various logging tools are described, including gamma ray, resistivity, density, neutron, and sonic logs which provide data on formation properties like lithology, porosity, and fluid content. Nuclear logs using gamma rays and neutrons can evaluate formations through casing as well.
This document summarizes the process of reservoir modeling and simulation for the Saldanadi Gas Field in Bangladesh using Petrel 2009.1.1 and FrontSim software. The workflow includes collecting seismic, well, and production data; interpreting horizons and faults from seismic lines; developing structural and stratigraphic models; modeling properties; simulating initial conditions and production; and history matching simulation results to field data. The objectives are to better understand reservoir characteristics, locate new wells, and forecast production and investment needs to further develop the field.
This document provides an overview of wellbore hydraulics and the theoretical basis for calculating static bottomhole pressures in gas wells. It discusses the energy relationships involved in fluid flow, including terms for internal energy, kinetic energy, potential energy, pressure energy, heat, and work. It also covers irreversibility losses due to friction. The document presents equations that relate these factors and can be used to directly calculate static bottomhole pressures based on known surface conditions, using tables of pseudocritical properties to account for gas compressibility with varying pressure.
Brief review on Direct hydrocarbon indicators (DHI).
The presentation is a part from Seismic data interpretation course that i teach for undergraduates.
The sources are indicated in the references list.
Contact me via: hatem_refaat95@hotmail.com
The document discusses the basics of well logging design. It includes an agenda for a one-day course that covers basic logging theory, interpretation, logging program design, and a workshop. The objectives are to familiarize participants with various log measurements, well evaluation strategies, and approaches to well logging design. Key logging topics covered include definitions, history, measurement principles for resistivity, spontaneous potential, gamma ray, density, neutron, and acoustic logs. Interpretation applications and limitations are also discussed.
This document discusses different types of oil reservoirs based on their driving mechanisms and fluid compositions. There are six main driving mechanisms that provide natural energy for oil recovery: rock and liquid expansion, depletion, gas cap, water, gravity, and combination drives. Reservoirs are also classified based on their initial pressure and temperature relative to the fluid properties. Depending on initial reservoir pressure compared to the bubble point pressure, reservoirs can be undersaturated, saturated, or gas-cap. Gas reservoirs are classified based on their phase diagrams as retrograde gas-condensate, near-critical gas-condensate, wet gas, or dry gas. Development considerations vary depending on the reservoir type and conditions.
WELL LOG : Types of Logs, The Bore Hole Image, Interpreting Geophysical Well Logs, applications, Production logs, Well Log Classification and Cataloging
Ppt 29-03-2017-reservoir characterisation and 3-d static modelling of “awe fi...Toba Awe
The document presents reservoir characterization and 3D static modeling of the Awe Field in the Niger Delta. Key findings include:
1. Petrophysical analysis of two reservoirs, G and I, across five wells found reservoir G has better porosity (29%) and permeability (262.5 mD) than reservoir I (26% porosity, 77.06 mD permeability).
2. 3D seismic interpretation identified faults within the field and mapped reservoir structure. Reservoir G contains two main faults while reservoir I has one minor fault.
3. Static modeling estimated reservoir G has a stock tank oil initially in place of 156 MMSTB while reservoir I contains 127 MMSTB, indicating reservoir G has greater
The Fullbore Formation MicroImager (FMI) instrument provides high resolution images of bedding and fractures in borehole walls. It uses electrical resistivity contrasts to image features around the borehole at vertical resolutions of 5 mm. FMI data is processed using Schlumberger software to correct speed, equalize histograms, and enhance images. FMI can be used for structural analysis, reservoir characterization of natural fractures and porosity, thin bed detection, and other applications. It images features like dips, fractures, vugs, laminations, and other sedimentological structures.
The document discusses definitions and categories of petroleum reserves based on probabilities of production. It defines proven, probable, and possible reserves, which have 90%, 50%, and 10% certainty of being produced, respectively. Methods for estimating reserves are described, including volumetric analysis, decline curve analysis, and production forecasting based on projected prices, costs, and other factors.
The importance of geohazards for safety, rig/well integrity & drilling. It includes real incidents & worst case scenarios. Pressure concepts, seismic and diagrams are utilized to explain given examples.
Formation evaluation is the process of interpreting measurements taken inside a wellbore to detect and quantify oil and gas reserves. It involves mud logging during drilling, coring to obtain formation samples, open-hole logging before casing, logging while drilling for real-time data, formation testing to obtain fluid samples and pressure measurements, and cased-hole logging after well completion. The data are used to evaluate reservoirs and predict fluid flow for optimal hydrocarbon recovery.
Farida Ismayilova has over 3 years of experience working for BP in drilling geohazards and PPFG specialization. She has a Bachelor's and Master's degree in Petroleum Engineering from Azerbaijan State Oil and Industry University. The presentation provides an overview of PPFG terms and principles, and the role of PPFG in well planning. It discusses basics like pore pressure, fracture gradient, and the PPFG window. It also explains how a PPFG specialist incorporates data from nearby wells to estimate high, base, and low cases for safe well design and mud weight selection.
This document provides an overview of basic well logs, including caliper logs, gamma ray logs, and formation density logs. It discusses the tools, principles, and uses of each log. Caliper logs measure borehole diameter and shape using mechanical arms. Gamma ray logs measure natural radiation from formations to indicate lithology. Formation density logs use gamma rays to measure bulk density and derive porosity, helping to identify lithologies when used with neutron logs. The document provides details on how each tool works and the information provided by its logs.
This document discusses special core analysis techniques used to measure relative permeability in rock samples. Special core analysis involves flow experiments on core samples to determine two-phase flow properties and relative permeability. The document describes methods to measure relative permeability, including maintaining intimate contact between core samples during steady fluid flow. It also discusses factors that influence relative permeability measurements like wettability alterations and saturation history effects during gas and water displacement processes. Capillary pressure tests and different capillary pressure measurement methods are also summarized.
Formation evaluation and well logging are processes used to determine the properties of subsurface reservoirs and identify commercially viable oil and gas fields. Key logging tools developed over time include resistivity logs in the 1920s, dipmeters in the 1940s, gamma ray and neutron logs in the 1940s, sonic logs in the 1950s, density logs in the 1960s, and logging while drilling was introduced, allowing real-time data acquisition. The document provides a historical overview of the development of various openhole well logging tools and techniques.
HPHT (High Pressure - High Temperature) wells have a downhole environment of more than 10,000psi (690 bar) and/or 300 deg F (140 deg C). These conditions are increasingly encountered in many basins worldwide, as exploration and production examine deeper and hotter objectives.
In attending this course, participants will gain knowledge and develops skills relating to HPHT Well Engineering. The course focuses on key characteristics and challenges of HPHT wells from well design, planning, engineering and operational perspectives.
Petroleum Production Engineering, Elsevier (2007) (2).pdfMohammedFouadAmeen
This document provides a preface and overview for a textbook on petroleum production engineering. It was written to provide modern production engineers with information on applying engineering principles to solve problems using computer technologies. The book is organized into four parts covering fundamentals, design principles, artificial lift methods, and production enhancement techniques. It focuses on illustrating principles through examples and provides companion spreadsheet programs to help engineers perform daily work efficiently.
This document discusses spontaneous potential (SP) logs. It explains that SP logs measure natural electrical potentials that occur between borehole fluids and formations. The potentials are caused by differences in salinity between drilling mud and formation waters. SP logs can detect permeable zones, boundaries, and determine water resistivity. The main components of SP are the membrane potential, caused by shale acting as an ion sieve, and the liquid junction potential, caused by ion diffusion between fluids of different salinities. Together these make up the total electrochemical potential measured on SP logs.
delta plain, delta front, and prodelta sedimentation.pptxSaadTaman
The document discusses the classification of lithofacies and bounding surfaces in continental delta deposits. It divides bounding surfaces into 6 hierarchical levels based on depositional scale, and identifies 14 basic lithofacies types in continental lacustrine basin deltas. Key lithofacies include conglomerate, sandstone, siltstone, and mudstone facies. Gilbert-type fan deltas are also discussed as being common in ancient lakes located at steep slope zones near basin edges.
18 09-2008 Francisco Nepomuceno Filho na Rio Oil and gas Expo Conference no R...Petrobras
O documento descreve as experiências da Petrobras no pré-sal, incluindo descobertas de campos gigantes nas bacias de Santos e Campos abaixo de 2.000 metros de sal com reservatórios de óleo leve e gás. Apresenta também as tecnologias utilizadas como FPSOs e poços de alta produtividade para a exploração dessas reservas.
The document summarizes the pre-salt reservoirs offshore Brazil from the perspective of Petrobras. It describes several significant oil discoveries with light oil in the Tupi area and other parts of the Santos and Campos basins. Extended well tests are planned to better understand reservoir behavior. Technological challenges include drilling through salt layers, flow assurance over long distances, and developing production facilities in deep water. Petrobras is pursuing strategies like standardization and partnerships to help meet these challenges through internal technology programs.
The document discusses the classification of well logs. It explains that logs can be classified based on their technology (open hole vs cased hole logs) or their function (lithology, electrical, porosity, nuclear logs). Open hole logs are run before casing while cased hole logs are done after casing through the metal piping. Various logging tools are described, including gamma ray, resistivity, density, neutron, and sonic logs which provide data on formation properties like lithology, porosity, and fluid content. Nuclear logs using gamma rays and neutrons can evaluate formations through casing as well.
This document summarizes the process of reservoir modeling and simulation for the Saldanadi Gas Field in Bangladesh using Petrel 2009.1.1 and FrontSim software. The workflow includes collecting seismic, well, and production data; interpreting horizons and faults from seismic lines; developing structural and stratigraphic models; modeling properties; simulating initial conditions and production; and history matching simulation results to field data. The objectives are to better understand reservoir characteristics, locate new wells, and forecast production and investment needs to further develop the field.
This document provides an overview of wellbore hydraulics and the theoretical basis for calculating static bottomhole pressures in gas wells. It discusses the energy relationships involved in fluid flow, including terms for internal energy, kinetic energy, potential energy, pressure energy, heat, and work. It also covers irreversibility losses due to friction. The document presents equations that relate these factors and can be used to directly calculate static bottomhole pressures based on known surface conditions, using tables of pseudocritical properties to account for gas compressibility with varying pressure.
Brief review on Direct hydrocarbon indicators (DHI).
The presentation is a part from Seismic data interpretation course that i teach for undergraduates.
The sources are indicated in the references list.
Contact me via: hatem_refaat95@hotmail.com
The document discusses the basics of well logging design. It includes an agenda for a one-day course that covers basic logging theory, interpretation, logging program design, and a workshop. The objectives are to familiarize participants with various log measurements, well evaluation strategies, and approaches to well logging design. Key logging topics covered include definitions, history, measurement principles for resistivity, spontaneous potential, gamma ray, density, neutron, and acoustic logs. Interpretation applications and limitations are also discussed.
This document discusses different types of oil reservoirs based on their driving mechanisms and fluid compositions. There are six main driving mechanisms that provide natural energy for oil recovery: rock and liquid expansion, depletion, gas cap, water, gravity, and combination drives. Reservoirs are also classified based on their initial pressure and temperature relative to the fluid properties. Depending on initial reservoir pressure compared to the bubble point pressure, reservoirs can be undersaturated, saturated, or gas-cap. Gas reservoirs are classified based on their phase diagrams as retrograde gas-condensate, near-critical gas-condensate, wet gas, or dry gas. Development considerations vary depending on the reservoir type and conditions.
WELL LOG : Types of Logs, The Bore Hole Image, Interpreting Geophysical Well Logs, applications, Production logs, Well Log Classification and Cataloging
Ppt 29-03-2017-reservoir characterisation and 3-d static modelling of “awe fi...Toba Awe
The document presents reservoir characterization and 3D static modeling of the Awe Field in the Niger Delta. Key findings include:
1. Petrophysical analysis of two reservoirs, G and I, across five wells found reservoir G has better porosity (29%) and permeability (262.5 mD) than reservoir I (26% porosity, 77.06 mD permeability).
2. 3D seismic interpretation identified faults within the field and mapped reservoir structure. Reservoir G contains two main faults while reservoir I has one minor fault.
3. Static modeling estimated reservoir G has a stock tank oil initially in place of 156 MMSTB while reservoir I contains 127 MMSTB, indicating reservoir G has greater
The Fullbore Formation MicroImager (FMI) instrument provides high resolution images of bedding and fractures in borehole walls. It uses electrical resistivity contrasts to image features around the borehole at vertical resolutions of 5 mm. FMI data is processed using Schlumberger software to correct speed, equalize histograms, and enhance images. FMI can be used for structural analysis, reservoir characterization of natural fractures and porosity, thin bed detection, and other applications. It images features like dips, fractures, vugs, laminations, and other sedimentological structures.
The document discusses definitions and categories of petroleum reserves based on probabilities of production. It defines proven, probable, and possible reserves, which have 90%, 50%, and 10% certainty of being produced, respectively. Methods for estimating reserves are described, including volumetric analysis, decline curve analysis, and production forecasting based on projected prices, costs, and other factors.
The importance of geohazards for safety, rig/well integrity & drilling. It includes real incidents & worst case scenarios. Pressure concepts, seismic and diagrams are utilized to explain given examples.
Formation evaluation is the process of interpreting measurements taken inside a wellbore to detect and quantify oil and gas reserves. It involves mud logging during drilling, coring to obtain formation samples, open-hole logging before casing, logging while drilling for real-time data, formation testing to obtain fluid samples and pressure measurements, and cased-hole logging after well completion. The data are used to evaluate reservoirs and predict fluid flow for optimal hydrocarbon recovery.
Farida Ismayilova has over 3 years of experience working for BP in drilling geohazards and PPFG specialization. She has a Bachelor's and Master's degree in Petroleum Engineering from Azerbaijan State Oil and Industry University. The presentation provides an overview of PPFG terms and principles, and the role of PPFG in well planning. It discusses basics like pore pressure, fracture gradient, and the PPFG window. It also explains how a PPFG specialist incorporates data from nearby wells to estimate high, base, and low cases for safe well design and mud weight selection.
This document provides an overview of basic well logs, including caliper logs, gamma ray logs, and formation density logs. It discusses the tools, principles, and uses of each log. Caliper logs measure borehole diameter and shape using mechanical arms. Gamma ray logs measure natural radiation from formations to indicate lithology. Formation density logs use gamma rays to measure bulk density and derive porosity, helping to identify lithologies when used with neutron logs. The document provides details on how each tool works and the information provided by its logs.
This document discusses special core analysis techniques used to measure relative permeability in rock samples. Special core analysis involves flow experiments on core samples to determine two-phase flow properties and relative permeability. The document describes methods to measure relative permeability, including maintaining intimate contact between core samples during steady fluid flow. It also discusses factors that influence relative permeability measurements like wettability alterations and saturation history effects during gas and water displacement processes. Capillary pressure tests and different capillary pressure measurement methods are also summarized.
Formation evaluation and well logging are processes used to determine the properties of subsurface reservoirs and identify commercially viable oil and gas fields. Key logging tools developed over time include resistivity logs in the 1920s, dipmeters in the 1940s, gamma ray and neutron logs in the 1940s, sonic logs in the 1950s, density logs in the 1960s, and logging while drilling was introduced, allowing real-time data acquisition. The document provides a historical overview of the development of various openhole well logging tools and techniques.
HPHT (High Pressure - High Temperature) wells have a downhole environment of more than 10,000psi (690 bar) and/or 300 deg F (140 deg C). These conditions are increasingly encountered in many basins worldwide, as exploration and production examine deeper and hotter objectives.
In attending this course, participants will gain knowledge and develops skills relating to HPHT Well Engineering. The course focuses on key characteristics and challenges of HPHT wells from well design, planning, engineering and operational perspectives.
Petroleum Production Engineering, Elsevier (2007) (2).pdfMohammedFouadAmeen
This document provides a preface and overview for a textbook on petroleum production engineering. It was written to provide modern production engineers with information on applying engineering principles to solve problems using computer technologies. The book is organized into four parts covering fundamentals, design principles, artificial lift methods, and production enhancement techniques. It focuses on illustrating principles through examples and provides companion spreadsheet programs to help engineers perform daily work efficiently.
This document discusses spontaneous potential (SP) logs. It explains that SP logs measure natural electrical potentials that occur between borehole fluids and formations. The potentials are caused by differences in salinity between drilling mud and formation waters. SP logs can detect permeable zones, boundaries, and determine water resistivity. The main components of SP are the membrane potential, caused by shale acting as an ion sieve, and the liquid junction potential, caused by ion diffusion between fluids of different salinities. Together these make up the total electrochemical potential measured on SP logs.
delta plain, delta front, and prodelta sedimentation.pptxSaadTaman
The document discusses the classification of lithofacies and bounding surfaces in continental delta deposits. It divides bounding surfaces into 6 hierarchical levels based on depositional scale, and identifies 14 basic lithofacies types in continental lacustrine basin deltas. Key lithofacies include conglomerate, sandstone, siltstone, and mudstone facies. Gilbert-type fan deltas are also discussed as being common in ancient lakes located at steep slope zones near basin edges.
18 09-2008 Francisco Nepomuceno Filho na Rio Oil and gas Expo Conference no R...Petrobras
O documento descreve as experiências da Petrobras no pré-sal, incluindo descobertas de campos gigantes nas bacias de Santos e Campos abaixo de 2.000 metros de sal com reservatórios de óleo leve e gás. Apresenta também as tecnologias utilizadas como FPSOs e poços de alta produtividade para a exploração dessas reservas.
The document summarizes the pre-salt reservoirs offshore Brazil from the perspective of Petrobras. It describes several significant oil discoveries with light oil in the Tupi area and other parts of the Santos and Campos basins. Extended well tests are planned to better understand reservoir behavior. Technological challenges include drilling through salt layers, flow assurance over long distances, and developing production facilities in deep water. Petrobras is pursuing strategies like standardization and partnerships to help meet these challenges through internal technology programs.
Antonio Carlos Pinto - "Pre-Salt: Challenges and Opportunities for the Brazil...Petrobras
- History: Petrobras has had major oil discoveries in Brazil's pre-salt province since the late 1990s and has pursued an aggressive exploration and development strategy focused on these reserves.
- Development Strategy: Petrobras' strategy involves phased development beginning with appraisal wells and pilots and ramping up to over 1 million barrels per day of production by 2016 utilizing new technologies.
- Opportunities: The pre-salt reserves provide opportunities for Petrobras to invest heavily in new technologies, local content policies, and partnerships to develop the challenging deepwater fields while doubling Brazilian oil production over the next decade.
This document summarizes information about Brazil's pre-salt reservoirs presented at the PRE SALT TECH 3rd Annual conference in April 2014. It describes the geology and characteristics of pre-salt reservoirs, the main technological challenges of exploiting them, and provides an overview of exploration and production activities and operators in the Campos and Santos basins. Production from pre-salt reservoirs had reached 127 million barrels of oil by 2012 and was forecasted to grow substantially with development of large new fields like Libra.
This document provides an update on Brazil's pre-salt oil and gas reserves. It summarizes key developments including increasing production from pre-salt fields in the Campos and Santos basins through expanded drilling and new production units coming online. Production has ramped up significantly from initial test wells to over 700,000 barrels per day currently. New technologies have been applied including deeper wells and new types of risers. Pre-salt fields provide competitive production costs and represent Brazil's role in global energy supply.
The document summarizes key events in Petrobras' exploration and development efforts from the 1950s to early 2000s. It highlights how Petrobras' geologists and geophysicists overcame challenges through technological innovation and training to make major offshore oil discoveries like Guaricema (1968), Namorado (1975), and the giant Tupi field (2001). The adoption of new seismic technologies like 2D, 3D, and 4D seismic helped reveal new exploration opportunities and increase recovery from fields like Marlim. Continuous training both within Petrobras and with foreign universities helped develop expertise in areas like deepwater exploration that unlocked major new resources for Brazil.
"Petrobras Domestic E&P - Results and Perspectives" Petrobras
The document provides an overview of Petrobras' domestic exploration and production strategy and operations. Key points include:
- Petrobras aims to increase production and reserves by strengthening expertise in deep waters and optimizing recovery from existing fields.
- As of 2005, Petrobras had proven reserves of 11.8 billion barrels of oil equivalent and produced 1,958 thousand barrels of oil equivalent per day.
- Production is forecasted to increase to 4,556 thousand barrels of oil equivalent per day by 2015, with oil and natural gas production both growing substantially.
- Petrobras seeks to guarantee long-term energy self-sufficiency for Brazil through sustainable reserve replacement and production growth.
The document discusses opposition to petroleum exploration permits granted by the New Zealand Crown to Petrobras in the Raukumara Basin off the East Coast of New Zealand's North Island. There are concerns about the environmental risks of offshore drilling, Petrobras' safety record, lack of consultation and compensation to Maori, and the Crown's unilateral claim to minerals. Strategies of non-violent resistance to influence decision makers and build support are outlined.
The document provides specifications for the Petrojarl Varg, an FPSO vessel owned by Teekay Petrojarl. It details that the Petrojarl Varg was a new build delivered in 1998 with a storage capacity of 470,000 barrels and can process up to 57,000 barrels of oil per day. It is currently in lay-up in Stavanger, Norway.
Pre-salt: overview and opportunities - Rio Oil & Gas 2012Petrobras
The document provides an overview of Petrobras' pre-salt strategy and results. Key points include:
- Petrobras has a strategy of performing extended well tests and pilot production to appraise pre-salt fields before full development.
- Exploration success rates in the Santos Basin pre-salt have exceeded 90%, resulting in major discoveries like Lula and Sapinhoá.
- The Lula Pilot was a pioneering project that demonstrated the productivity and potential of pre-salt reservoirs.
- Production from pre-salt fields is expected to increase significantly through 2020 to over 4 million barrels per day.
The FPSO Cidade de Itajaí is a converted FPSO vessel operating in the Tiro e Sidon Field offshore Brazil for Petrobras. It has a production capacity of 80,000 barrels of oil per day and storage capacity of 650,000 barrels. The FPSO is spread moored with 16 lines and can operate in water depths between 70-1000 meters.
The document discusses Petrobras' growing investments and production challenges and opportunities. Petrobras plans to invest over $200 billion between 2008-2012 to develop major new oil fields, increasing production from around 2 million barrels per day currently to over 4 million barrels per day by 2012. This will require contracting numerous offshore drilling rigs, vessels, equipment and expanding infrastructure. The company is also promoting programs to develop Brazil's national oil and gas industry to supply the growing needs.
Brazil petroleum and natural gas market outlook to 2016 executive summaryAMMindpower
The report titled “Brazil Petroleum and Natural Gas Market Outlook to 2016 - Opportunities in Pre-Salt Region” provides a comprehensive analysis of market size of petroleum and natural gas industry on the basis of petroleum industry and natural gas industry.
Outlook of oil and gas in Brazil - Kormarine 2013Claudio A. Pinho
The document discusses the oil and gas industry and opportunities in Brazil, presented by Claudio A. Pinho on October 23, 2013. It provides information on Brazil's regulatory framework for oil and gas, bidding rounds conducted by ANP, opportunities for suppliers, the current scenario and perspectives, offshore infrastructure including an offshore nautical hub, local content policies, and challenges for doing business in Brazil such as bureaucracy, taxes, and local content requirements.
This document discusses the challenges of unitizing oil and gas reservoirs that span multiple contractual agreements in Brazil's pre-salt area. It notes there are currently three types of international petroleum agreements - concessions, onerous assignments, and production sharing agreements. Unitizing these different agreements introduces complexities around issues like local content requirements, government take, fiscal regimes, and operatorship. The document analyzes two hypothetical unitization scenarios and potential solutions to problems that may arise, though it notes more specific contractual and regulatory analysis is needed. Overall, unitizing pre-salt reservoirs with multiple agreement types presents significant technical and legal challenges under Brazil's framework.
Edition 41 - Sharing in Petrobras - March/2014Petrobras
- Strategic Plan: horizon 2030
- 2014-2018 Business and Management Plan
- Declaration of commerciality in Transfer of Rights areas
- Libra Consortium
- Capital raising abroad
- 2013 net income was R$ 23.6 billion
- Oil and natural gas output expected to rise 7.5% in 2014
- Record in the pre-salt: 412,000 barrels/day
- Rising output at Cascade and Chinook
- New regasification terminal in Bahia
- Petrobras returns to F1 with Willians Martini Racing
- Cenpes turns 50
- Ultra-low sulfur gasoline launched in Brazil
Pre-Salt Oil - Developing The Frontier | CEO José Sergio Gabrielli de Azevedo...Petrobras
The document summarizes key points about Brazil's pre-salt oil development:
1) Pre-salt oil fields have had a short lag between discovery and first oil production, and are projected to ramp up production faster than other frontier developments like the Gulf of Mexico or North Sea.
2) Santos Basin pre-salt development from 2006-2010 included infrastructure build-out and multiple discoveries.
3) Further development from 2011-2016+ includes additional pipelines, production units, rigs, and discoveries to enable faster ramp-up to full capacity.
4) While capital costs are similar to deepwater Campos Basin projects, pre-salt may have higher drilling/completion costs partially offset by larger reserves
01.06.2009 Presentation of Investor Relations Executive Manager, Theodore M....Petrobras
Petrobras is a large, integrated energy company headquartered in Brazil. It operates across the entire oil and gas value chain, including exploration and production, refining, transportation and marketing. Some key points:
- Petrobras has significant oil and gas reserves, especially in large pre-salt fields located off the coast of Brazil. It is investing heavily to develop these reserves.
- Production is expected to grow substantially through 2020 as more pre-salt and other new fields come online, especially in Brazil.
- Petrobras maintains financial discipline and targets an investment-grade credit rating. It carefully plans investments to support growth while managing leverage.
- The company has a dominant position in Brazil
The document discusses Brazil's large pre-salt oil and natural gas reserves located deep beneath the ocean floor and the challenges and opportunities they present. Brazil's pre-salt reserves are estimated to increase oil production to 8 million barrels per day. Developing these reserves will require huge investments, estimated at $600 billion over 30 years. As Brazil's production grows, it has signed agreements to sell excess oil to China and the United States. The document also discusses potential pre-salt reserves off the coast of Africa and how Brazil's experience developing its own pre-salt fields could benefit Africa going forward.
Petrobras Business and Management Plan 2013-2017 Webcast - March 19thPetrobras
The document provides a business and management plan for 2013-2017. It summarizes key targets including maintaining oil and gas production around 2 million barrels per day. It also discusses investments made in 2012 that achieved planned targets. Successful exploration led to 53 discoveries from 2012-2013, including 15 pre-salt finds. Pre-salt production reached 300,000 barrels per day in early 2013. Refining capacity is also increasing with new refineries coming online.
The document is the results announcement for Petrobras' 3rd quarter 2009. It contains the following key points:
1. Petrobras saw an 8% increase in total production and a 5% rise in domestic oil production compared to the third quarter of 2008.
2. New production units are ramping up and expected to further increase output. Pre-salt activities are accelerating with ongoing exploration and appraisal wells.
3. Operating income was impacted by a provision for special participation tax related to the Marlim field, but net income was flat after adjusting for foreign exchange variations.
4. Exploration and production showed solid operating performance while downstream income normalized with increases in international prices. Gas and energy
Petróleo Brasileiro S.A. - PETROBRAS is Brazil's state-controlled oil company. It presented at the World Money Show in February 2007. The presentation discusses PETROBRAS' typical deepwater production projects using semi-submersible platforms and floating storage and offloading vessels. It also highlights several new production platforms coming online in 2007 that would increase its oil production capacity by 560,000 barrels per day. PETROBRAS is a major international integrated energy company with operations in exploration and production, refining, petrochemicals, gas and power.
The document provides information on Myanmar's oil and gas exploration program and key projects. It outlines MOGE's goals to explore and produce oil and gas onshore for self-sufficiency and oversee production sharing contracts offshore. It lists Myanmar's major onshore and offshore oil and gas fields and concessions. It provides details on the Yadana and Yetagun offshore gas projects including reserves, sellers, buyers, facilities, and export details. It also discusses recent gas discoveries in Blocks A-1, A-3, M-9 including the Zawtika and Shwe Pyi Htay fields and potential utilization options for the discovered gas.
Petrobras announced its second quarter 2010 results. Net income increased 7% to R$8.3 billion. New oil discoveries in the Campos Basin pre-salt are estimated to contain 500 million barrels of recoverable oil. Production is increasing with the start-up of new production units such as the FPSO Capixaba in Espírito Santo. Planned investments total $224 billion through 2014 according to the new business plan. Oil and gas production increased year-over-year due to contributions from new projects.
This document provides a summary of SBM Offshore's 2009 results and outlook. Key highlights include net profits of $230 million and record backlog of $10 billion despite lower new orders. Major projects delivered in 2009 included FPSOs in Brazil and the Gulf of Mexico. The company's lease fleet consists of 18 units under long-term contracts. SBM Offshore is focused on cost control and executing major projects in 2010 while pursuing new technologies like LNG FPSO and wave energy conversion.
Strategic Plan 2040 || Business and Management Plan 2019-2023Petrobras
The presentation contains forward-looking statements about future events that are not based on historical facts and are not assurances of future results. Such statements merely reflect the Company’s current views and estimates of future economic circumstances, industry conditions, company performance and financial results. Readers are cautioned that these statements are only projections and may differ materially from actual future results or events. The document also contains certain financial measures that are not recognized under Brazilian GAAP or IFRS and may not be comparable to similarly-titled measures provided by other companies.
Plano Estratégico 2040 || Plano de Negócios e Gestão 2019-2023Petrobras
Este documento descreve a jornada da companhia até o momento, suas ambições para o futuro e os planos para alcançá-las. A companhia busca reduzir custos, dívida e riscos, enquanto aumenta a produção, rentabilidade e investimentos em novas áreas, como renováveis. Seus principais objetivos incluem reduzir acidentes, dívida e aumentar retorno sobre capital empregado.
Petrobras provides an overview and highlights of its operations in the first half of 2018. Key points include a net income of $17 billion, an 18% increase in operating income, and starting production from the first system in the Transfer of Rights area of the Buzios field. Petrobras also anticipates increasing production through 2022 by starting up 19 new production units and expanding its exploratory portfolio by 31% since 2017. The company aims to reduce debt levels through divestments and maintain its 2018-2022 capex at $74.5 billion, focusing investments on pre-salt areas and projects with higher profitability.
Apresentação Investor Day, São Paulo, 2018Petrobras
O documento apresenta as informações da reunião anual com investidores da Petrobras em 2018. Nele, o presidente da Petrobras discute os principais destaques da companhia no ano, incluindo a redução da dívida líquida, aumento do fluxo de caixa livre e entrega consistente das metas de produção. Além disso, o documento aborda a melhoria da governança corporativa e da gestão de riscos da Petrobras.
- Petrobras held its annual investor day in 2018 to discuss the company's performance and future plans
- The CEO highlighted improvements in safety, debt reduction, cash generation, governance, and exploration successes in recent years
- Executives provided details on ongoing debt management initiatives, production increases, cost savings, and new deepwater project startups
- The company aims to further strengthen its financial position while preparing for a low-carbon future through technology investments and portfolio optimization
O documento fornece informações sobre as atividades e desempenho da Petrobras em 2017, incluindo sua transição para uma economia de baixo carbono, transformação digital, desempenho operacional e financeiro, segurança e saúde dos trabalhadores, e contribuições para a sociedade e meio ambiente. A mensagem do presidente destaca os compromissos da empresa com a sustentabilidade, como investimentos em novas tecnologias de baixo carbono e redução de emissões.
FORWARD-LOOKING STATEMENTS:
DISCLAIMER
The presentation may contain forward-looking statements about future events within the meaning of Section 27 A of the Securities Act of 1933, as amended, and Section 21 E of the Securities Exchange Act of 1934, as amended, that are not based on historical facts and are not assurances of future results. Such forward-looking statements merely reflect the Company’s current views and estimates of future economic
circumstances, industry conditions, company performance and
financial results. Such terms as "anticipate", "believe", "expect",
"forecast", "intend", "plan", "project", "seek", "should", along with similar or analogous expressions, are used to identify such forward-looking statements. Readers are cautioned that these statements are only projections and may differ materially from
actual future results or events. Readers are referred to the documents filed by the Company with the SEC, specifically the Company’s most recent Annual Report on Form 20-F, which identify important risk factors that could cause actual results to differ from those contained in the forward-looking statements,
including, among other things, risks relating to general economic
and business conditions, including crude oil and other commodity prices, refining margins and prevailing exchange rates, uncertainties inherent in making estimates of our oil and
gas reserves including recently discovered oil and gas reserves,
international and Brazilian political, economic and social developments, receipt of governmental approvals and licenses and our ability to obtain financing.
Este documento descreve:
1) As previsões contidas na apresentação envolvem riscos e incertezas e não são garantias de resultados futuros.
2) A companhia não se obriga a atualizar previsões com novas informações.
3) Alguns indicadores financeiros não são reconhecidos pelo BR GAAP ou IFRS e não devem ser usados isoladamente.
Apresentação de Pedro Parente no Investor Day Nova YorkPetrobras
Petrobras CEO Pedro Parente presented at an event in New York on October 2, 2017. The presentation included disclaimers about forward-looking statements and non-SEC compliant reserves data. It discussed Petrobras' strengths in deepwater production, integrated operations across Brazil's energy industry, and ongoing work to improve governance, reduce costs and leverage through partnerships and divestments. The Business Plan aims to lower leverage, reduce injury rates, focus capital expenditures, and lower production costs.
Apresentação de Pedro Parente no Investor Day LondresPetrobras
1. The document contains a disclaimer stating that any forward-looking statements are based on estimates and are subject to risks and uncertainties.
2. It then outlines an agenda for a Petrobras Day presentation, including discussing Petrobras at a glance, the oil and gas industry, Brazil's regulatory framework, Petrobras' strengths, recent results, and future planning.
3. The document provides several cautions about non-SEC compliant data and financial measures included in the presentation.
Apresentação de Pedro Parente no Investor Day São PauloPetrobras
1) O documento apresenta avisos sobre previsões e estimativas contidas no material.
2) É informado que termos como "descobertas" não podem ser usados nos relatórios arquivados da companhia segundo as diretrizes da SEC.
3) Há um aviso para investidores norte-americanos sobre indicadores financeiros não reconhecidos pelo BR GAAP ou IFRS.
Este documento apresenta o plano estratégico e de negócios da Petrobras para 2017-2021. O plano visa reduzir custos operacionais em 18% e a dívida líquida da empresa através de parcerias e desinvestimentos. O plano também prevê aumentar a produção de petróleo e gás natural por meio de novos projetos de exploração e produção, principalmente no pré-sal.
Petrobras presents its Strategic Plan for 2017-2021 which focuses on oil and gas production. Key goals include reducing total recordable injury rate by 36% and reducing leverage (net debt to EBITDA ratio) to 1.4 by 2018. The plan prioritizes cost reductions through operational efficiencies, partnerships and divestments. Planned investments total $74.1 billion, with 81% directed towards exploration and production. The plan expects to increase oil and gas production to 3.34 million boe/day by 2021 through development of pre-salt and post-salt assets. Financial measures aim to fund investments without taking on additional net debt over the period.
Strategic Plan and 2017-2021 Business & Management PlanPetrobras
This document outlines Petrobras' strategic plan for 2017-2021. It discusses where the company is currently, with high debt levels and operating costs, and where it wants to be - an integrated energy company focused on oil and gas. The plan details how Petrobras will get there through initiatives like cost reductions, partnerships and divestments, and lower capital expenditures. It establishes metrics to measure success in areas like safety, financial leverage, and production levels. The strategies discussed include optimizing the exploration and production portfolio, increasing efficiency in deepwater production, and strengthening refining and natural gas operations.
Plano Estratégico e Plano de Negócios e Gestão 2017-2021Petrobras
Este documento apresenta o Plano Estratégico e de Negócios da empresa para o período de 2017-2021, com o objetivo de guiar a empresa rumo à sua visão de longo prazo. O plano descreve onde a empresa está atualmente, enfrentando desafios como endividamento e preços baixos de petróleo, e onde deseja chegar, com métricas focadas em segurança e redução da alavancagem. O plano também explica como a empresa pretende alcançar seus objetivos por meio de iniciativas de redução de custos, par
O Conselho de Administração da Petrobras aprovou o Plano de Negócios e Gestão 2015-2019, com objetivos de desalavancagem da companhia e geração de valor para acionistas. O plano prevê reduzir a alavancagem líquida para menos de 40% até 2018 e 35% até 2020, com desinvestimentos de US$ 15,1 bilhões em 2015-2016 e US$ 42,6 bilhões em 2017-2018. A produção total esperada é de 3,7 milhões de barris de óleo equivalente por dia em 2020, com o pré
1) A Petrobras divulgou seus resultados do primeiro trimestre de 2016, apresentando prejuízo líquido de R$ 1,2 bilhão.
2) Os resultados foram impactados negativamente pela queda nos preços do petróleo e câmbio desfavorável.
3) A produção total de petróleo e gás natural da Petrobras no Brasil e no exterior caiu 1% em relação ao trimestre anterior.
The document summarizes Petrobras' 1st quarter 2016 results. Net income decreased 123% to a loss of R$1.2 billion due to lower oil prices, weaker demand, and higher financial expenses. Oil and gas production declined 6% to 2.6 million boed. Lifting costs fell 21% in Brazil and 37% abroad. Refining costs decreased slightly. Downstream sales volumes declined 5-8% while refining utilization remained stable. Cash flow from operations fell 2% to US$6 billion. Investments declined 13% to R$15.6 billion.
ZKsync airdrop of 3.6 billion ZK tokens is scheduled by ZKsync for next week.pdfSOFTTECHHUB
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UnityNet World Environment Day Abraham Project 2024 Press ReleaseLHelferty
June 12, 2024 UnityNet International (#UNI) World Environment Day Abraham Project 2024 Press Release from Markham / Mississauga, Ontario in the, Greater Tkaronto Bioregion, Canada in the North American Great Lakes Watersheds of North America (Turtle Island).
Methanex is the world's largest producer and supplier of methanol. We create value through our leadership in the global production, marketing and delivery of methanol to customers. View our latest Investor Presentation for more details.
2. DISCLAIMER
FORWARD-LOOKING STATEMENTS
The presentation may contain forward-looking statements We undertake no obligation to publicly update or
about future events within the meaning of Section 27A of revise any forward-looking statements, whether as
the Securities Act of 1933, as amended, and Section 21E a result of new information or future events or for
of the Securities Exchange Act of 1934, as amended, that any other reason. Figures for 2012 on are
are not based on historical facts and are not assurances of estimates or targets.
future results. Such forward-looking statements merely
reflect the Company’s current views and estimates of
future economic circumstances, industry conditions, All forward-looking statements are expressly
company performance and financial results. Such terms qualified in their entirety by this cautionary
as "anticipate", "believe", "expect", "forecast", "intend", statement, and you should not place reliance on
"plan", "project", "seek", "should", along with similar or any forward-looking statement contained in this
analogous expressions, are used to identify such forward- presentation.
looking statements. Readers are cautioned that these
statements are only projections and may differ materially
from actual future results or events. Readers are referred NON-SEC COMPLIANT OIL AND GAS RESERVES:
to the documents filed by the Company with the SEC,
specifically the Company’s most recent Annual Report on CAUTIONARY STATEMENT FOR US INVESTORS
Form 20-F, which identify important risk factors that could We present certain data in this presentation, such
cause actual results to differ from those contained in the as oil and gas resources, that we are not permitted
forward-looking statements, including, among other to present in documents filed with the United
things, risks relating to general economic and business States Securities and Exchange Commission (SEC)
conditions, including crude oil and other commodity under new Subpart 1200 to Regulation S-K because
prices, refining margins and prevailing exchange rates, such terms do not qualify as proved, probable or
uncertainties inherent in making estimates of our oil and possible reserves under Rule 4-10(a) of Regulation
gas reserves including recently discovered oil and gas S-X.
reserves, international and Brazilian political, economic
and social developments, receipt of governmental
approvals and licenses and our ability to obtain financing.
20. SANTOS BASIN DEVELOPMENT
BP 2012-2016 AND STRATEGIC PLAN 2020 (FUTURE PARTICIPATION OF THE SANTOS BASIN)
DOMESTIC OIL PRODUCTION AND NATURAL GAS SUPPLY
(IMPORTANCE OF SANTOS BASIN)
• BP: 38 new Production Systems until 2020
• 25 in Santos Basin
• 24 in the Pre-Salt area
• Challenge: maximizing operational performance
21. PRODUCTION CURVE IN BRAZIL - OIL AND LNG
Post-Salt, Pre-Salt and Transfer of Rights
Production Curve in Brazil – Oil and LNG Production
2018 2019 2020
Franco 4 Maromba Espadarte III
2017 Sul de Guará Bonito Florim
2014 2015 2016 Lula Ext. Sul Júpiter Entorno de Iara
Norte Pq. Lula Alto Iara Horst Carcará
2013 Iracema Norte
Baleias (P-58) NE Tupi Sul Pq. Baleias
Lula Central
Piloto Sapinhoá Roncador IV Franco 5
Lula Sul Carimbé 4,200
(Cid. São Paulo) (P-62)
Franco 1 Aruanã Espadarte I
2012 Piloto Lula NE Sapinhoá Norte 12%
(Cid. Paraty) (Cid. Ilhabela) Carioca 1 Iara NW
Baleia Azul Papa-Terra Iracema Sul Lula Norte Franco 3
Thousands bpd
(Cid. Anchieta) (P-61 e P-63) (Cid. 19%
Franco 2
Baúna e Piracaba Roncador III Mangaratiba)
(Cid. Itajaí) (P-55) 2,500
1% 28%
2,022
30%
5%
95% Stable Prod. (± 2%) 4-6% p.y. Growth 69% 42%
2011 2012 2013 2014 2015 2016 2017 2018 2019 2020
Post-salt Pre-salt (Concession) Transfer of Rights New Discoveries*
(*) Includes new opportunities in blocks where discoveries have already been found
22. NATURAL GAS SUPPLY AND DEMAND (MILLION m³/d)
SUPPLY DEMAND
PCS 9.400 kcal/m³
Domestic NG Supply Thermo Power Plants Demand: Petrobras + Third Parties
52
46
81 (9,3 GW)
44 (8,0 GW)
68 (7,5 GW) To be contracted
48 6
6 6 North Region
4 32 34 35 Flexible
62 75
44 Other Regions Inflexible
12 12 11
2011 2016 2020 2011 2016 2020
Supply via LNG Regasification Terminals NG Distributors Demand
65
51
41 41
41
21 14 14
Bahia
Non–thermal power
7 7 7 Pecém
14 20 20 Guanabara Bay
2011 2016 2020 2011 2016 2020
Bolivian Supply Petrobras Demand: Downstream + Fertilizers
30 30 30
30
26
6 6 6 Flexible 14
5 5 Fertilizers
24 24 24 Firm 3
21 25 Downstream
11
2011 2016 2020 2011 2016 2020
99 139 152 Total 99 123 147 Total
Supply Demand
23. DOMESTIC PROVED RESERVES AND EXPLORATORY SUCCESS
The current reserve / production of
Over the past 20 years, Petrobras corresponds to 19.2 years
the proved reserves in
Brazil increased by In 2011, the Brazilian total increase in
164% reserves was 1.24 billion boe. Of this
total, 0.98 billion boe refers to Pre-Salt
+3% Exploratory Success (Brazil)
15,71 Pre-Salt:
15,28
13,23 94%*
( 2011)
+164% 9,65
57% 59%
7,53 40%
5,96
1991 1995 2000 2005 2010 2011 2009 2010 2011
* Index of exploratory success in the fields operated by
Proved Reserves (billion boe) Petrobras in the Pre-salt Area of Santos Basin
24. RESERVES AND RECOVERABLE VOLUMES
Rapid growth in reserves from discoveries in deep waters
Proved Reserves – SPE criteria
Million boe
Shallow-water
30.000
25.000
Pre-salt: Lula Pre-salt:
and Iracema Sapinhoá
15,70 Bi boe
20.000
Whales Park,
Mexilhão
15.000
Roncador
10.000
Marlim
5.000 Namorado
Guaricema Garoupa
Carmópolis
-
Onshore 0-300m 300-1500m > 1500m Pre-salt's Recovery Volume Transfer of Rights
* Lula/Iracema, Iara, Guará and Whales Park, ranging from 7.3 to 8.5 Billion boe
25. MAIN DISCOVERIES IN 2012
Date Basin Field Participation Quality of Estimated Water
the Oil Recoverable Volume Depth (m)
Production capacity:
3,295
Feb -12 Solimões Igarapé Chibata BR (100%) 41º API 1,400 bpd of oil
(Onshore)
45k m3 of gas
Right to produce up to
Feb -12 Santos Franco NW (TR) BR (100%) 28º API (Pre-Salt) 1,860
3.058 Bi boe
Feb -12 Santos Carioca Sela BR(45%) BG(30%) RPS(25%) 27º API (Pre-Salt) Not Disclosed 2,149
34º API (Bauna) 113 MM boe (Bauna)
Feb -12 Santos Bauna e Piracaba BR (100%) shallow water
32º API (Picaraba) 83 MM boe (Piracaba)
> 700 MM boe of oil
Feb -12 Campos Pão de Açucar BR(30%) RPS(35%) STO(35%) Pre-Salt Oil 2,800
545 MM boe of gas
Right to produce up to
Mar-12 Santos Tupi Northeast (TR) BR (100%) 26º Oil API (Pre-Salt) 2,131
428 MM boe
BR(66%) PGL(14%)
Mar-12 Santos Carcará 31º Oil API (Pre-Salt) Not Disclosed 2,027
BARRA(10%) QG(10%)
Apr-12 Santos Iara Oeste BR(65%) BG(25%) PGL(10%) 21º to 26º API (Pre-Salt) 3 to 4 Bi boe (BMS-11) 2,150
Apr-12 Santos Dolomita Sul BR (100%) Pre-salt Oil Not Disclosed 1,747
Right to produce up to 2,202
June-12 Santos Sul de Guará (TR) BR(45%) BG(30%) RPS(25%) 27º API (Pre-Salt)
319 MM boe
BR (40%) IBV(30%)
July -12 Esp.Santo Grana Padano 15º API Not Disclosed 1,208
ANADARKO(30%)
Aug-12 Ceará Pecém BR (60%) BP(40%) Oil Not Disclosed 2,129
Right to produce up to
Aug-12 Santos Franco SW (TR) BR (100%) 28º to 30º Oil API 2,024
3.058 Bi barrels oil
Aug-12 Sergipe Alagoas Barra BR (60%) IBV(40%) 38º API Not disclosed 2,433
light oil, gas and
Aug-12 Sergipe Alagoas Moita Bonita BR (100%) Not disclosed 2,775
condensate
Note: TR = Transfer of Rights
26. 2012-2016 CAPEX
Implementation Vs. Evaluation
Under Implementation Under Evaluation
2012-2016 BP = All E&P projects in Brazil and projects of the
remaining segments in phase IV*
+ Projects for the remaining segments
currently in phase I, II and III.
US$ 236.5 Billion US$ 208.7 Billion US$ 27.8 Billion
980 projects 833 projects 147 projects
27.7% 24.8% 17% (**)
(US$ 65.5 Billion) US$ 51.7 Billion (US$ 4.6 Billion)
28% 7%
(US$ 1.9 Billion)
0%
65.8% (US$ 0.1 Billion)
60.0% 3.7% 50%
(US$ 141.8 Billion) (US$ 137.2 Billion) (US$ 7.8 Billion) 5% (US$ 13.9 Billion)
5.8% (US$ 1.3 Billion)
1.8%
(US$ 13.8 Billion
(US$ 3.7 Billion)
2.1%
1.7%
(US$ 5.0 Billion)
(US$ 3.5 Billion) 21%
1.5%
(US$ 3.6 Billion) 0.9% (US$ 6.0 Billion)
1.6% (US$ 1.9 Billion)
1.4%
1.3% (US$ 3.8 Billion)
(US$ 3.0 Billion)
(US$ 3.0 Billion) ** E&P abroad
E&P RTM G&E Petrochemical Distribution Biofuel Corporate
* Includes budget already designated for projects under evaluation for RTM, G&E, Petrochemical, Distribution, Biofuels and Corporate
27. 2012-2016 CAPEX
Exploration & Production
Exploration
US$ 25.4 Billion
E&P
US$ 131.6 billion*
24%
(6) Pre-Salt
Post-Salt
19%
8% 69% Transfer of Rights
(US$ 25,4 Bi)
(2) (17.5)
12%
69% (US$ 16,3 Bi)
(US$ 89,9 Bi)
Production Development
US$ 89.9 Billion
Production Development
34%
Exploration Pre-Salt
49% (30.2)
Infrastructure and Support (43.7) Post-Salt
Transfer of Rights
18%
(16.3)
* Does not include International E&P investments
28. EXPLORATION INVESTMENTS IN BRAZIL
Focus on New Frontiers
Investments focused on:
• New Frontiers (Equatorial Margin and East Margin), to ensure a continued R/P ratio higher than 15 years
• Consolidation and appraisal of the Pre-salt and Transfer of rights areas
US$ 25.4 billion
Transfer of Rights Equatorial
Consolidation
and Appraisal
8% Margin
(2.0)
Pre-salt
24%
(6.0)
New Frontiers
East
69%
(17.5) Margin
Post-salt
Finding Cost (US$ / boe) Concession Areas
1.56 March, 2012
Petrobras
Other Companies
Petrobras Costs Lower than the Majors
(2007-2011): US$ 3.2 to 4.5 / boe
29. NEW PRODUCTION UNITS - 2012-2014
New platforms built domestically and abroad will contribute to production
Top Side / Local Content
Project Capacity 1st Oil Hull
Integration Commit. Target
Baleia Azul SBM
100 kbpd Sep/2012 Existing 0% 44%
FPSO Cid. Anchieta Cingapura
Baúna and Piracaba Jurong Odebrecht and Teekay
80 kbpd Dec/2012 60% 81%
FPSO Cid. Itajaí Cingapura Cingapura
Sapinhoá Pilot Cosco Shipyard Schahin/Modec
120 kbpd Jan/2013 30% 50%
FPSO Cid. São Paulo China Brasfels
Lula NE Pilot Keppel Shipyard QGOG/SBM
120 kbpd May/2013 30% 30%
FPSO Cid. Paraty Cingapura Brasfels
Papa-Terra Cosco Shipyard Quip
140 kbpd July/2013 0% 65%
P-63 China Rio Grande
Roncador Module III EAS Quip
180 kbpd Sep/2013 0% 65%
P-55 Brasil Rio Grande
Papa-Terra Natural Floatec Floatec
Oct/2013 0% 65%
P-61 Gas Brasfels Brasfels
Parque das Baleias Queiróz Galvão Queiróz Galvão
180 kbpd Jan/2014 0% 58%
P-58 Rio Grande Rio Grande
Roncador Module IV Camargo Corrêa/IESA Camargo Corrêa/IESA
180 kbpd Mar/2014 0% 65%
P-62 EAS EAS
Sapinhoá Norte QGOG/SBM QGOG/SBM
150 kbpd Sep/2014 30% 47%
FPSO Cid. Ilhabela China SBM/BRASA
Lula - Iracema Sul Cosco Shipyard
150 kbpd Nov/2014 Not define 30% 47%
FPSO Cid. Mangaratiba China
* Note: “FPSO Cid. XX” = Leased / “P-XX” = Owned 29
30. FPSO Cidade de Anchieta – Baleia Azul
Operating since Sep 10th, 2012
Production Ramp up Interconnection of
(bpd) Producing Wells
Sep/12 29,700 1st Well sep/10/12
Oct/12 52,185 2nd Well sep/21/12
Nov/12 52,185 3rd Well sep/26/12
Dec/12 72,000 4th Well nov/12/12
Peak (100 kbpd): Feb/13 5th Well nov/13/12
Local Content - Mandatory: 0%
Forecast Accomplishment : 44%
31. BrasFels Shipyard - RJ
4.200
Cid. São Paulo
Cid. São Paulo
Cid. Paraty
Cid. Paraty
P-61
P-61
2.500
2.022
Current Jobs: 7,000
2011 2012 2013 2014 2015 2016 2017 2018 2019 2020
2
3
1
View of BrasFels Shipyard, in Angra dos Reis – RJ (Aug 31st, 2012)
(1) P-61 (LC:65%): Construction of the HULL of the TLWP and integration of TOPSIDE (deckbox and modules constructed in Singapore).
(2) FPSO Cidade de São Paulo (LC:65%): Conversion of the HULL in China and integration of 15 modules, constructed in Brasfels (5 mod), Enaval (1 mod), Thailand (8 mod) and China (2
mod).
32. NEW PRODUCTION UNITS
Platforms under construction or already contracted will meet mid-term needs
8 Replicant FPSOs for Pre-Salt
• Oil Production Capacity: 150,000 bpd per unit
• Installation in Pre-salt areas BMS-9 and BMS-11
• Hulls under construction at Rio Grande Shipyard
• Contracts approved for the construction and integration of the topside modules
of the six first units: DM/TKK, IESA, Tome/Ferrostaal, Mendes Jr/OSX
• These contracts total US$ 4,5 billion
• The two remaining topside modules and integration package contracts are
expected to be awarded by 2013 with the same companies
4 VLCCs Conversion to FPSOs
• Oil Production Capacity: 150,000 bpd per unit
• Installation in Transfer of Rights Areas (Franco and Nordeste de Tupi)
• Conversion will be made at the Inhauma Shipyard
• Two units will be converted by 2014 and the other two by 2015
• The next stage will involve installing the oil and gas processing and
production plant modules and integrating the units
33. P-66
P-66 P-70
P-70
Rio Grande Shipyard – ERG1 - RS P-67
P-67 P-71
P-71
P-68
P-68 P-73
P-73
4.200
P-72
P-69
P-69
7
2.500
2.022 P-55 P-55
6
Empregos Atuais:3,500
Current Jobs: 3.500
2011 2012 2013 2014 2015 2016 2017 2018 2019 2020
5
4
1 3
3
2
View of Rio Grande Shipyard ERG1 – RS (Sep 3rd, 2012)
(1) Steel plates of Ecovix; (2) Sub-blocks of the Hulls of the replicants of Ecovix; (3) QUIP modules for Topside and integration of P-55; (4) Modules of the IESA; (5) Pre edification area , with
details for the yellow blocks of the Goliath crane type of the Konecranes (biggest crane in the world: 210m high and capacity of 2 thousand ton) delivered in Aug/12; (6) Work integration of P-55;
(7) Work construction of Rio Grande Shipyard ERG 2, where will be constructed 3 Drilling Rigs of Setebrasil (NS Cassino, NS Curumim e NS Salinas)
34. Inhaúma Shipyard- RJ
4.200
P-74
2.500
2.022
Current Jobs: 109
2011 2012 2013 2014 2015 2016 2017 2018 2019 2020
1
Overview of Inhaúma Shipyard, in Rio de Janeiro – RJ (Aug 31st, 2012)
(1) P-74: Hull´s conversion of VLCC ship (structural reinforcement of the hull, enlargement, reform and adaptation of arrangement, installations of equipments and adaptation of anchorage
system).
35. DRILLING RIGS AVAILABILITY
Necessity met with imported and domestic units
Drilling Rigs: Imported vs. Domestic
42 42 42 42 42
(Water Depth > 2.000m)
Number of Drilling Rigs
33 new domestic drilling rigs from 2016 on: Local Content between 55% and 65%
• Mid-term needs for drilling rigs are now largely satisfied. Future intermediate demand will be
limited to specific situations and needs.
• Starting in 2016, Brazilian built rigs expected to begin replacing internationally built fleet as
their contracts expire (and subject to total fleet needs).
• If for any reason the domestic rigs are not completed as scheduled, Petrobras has the possibility
of renewing some or all of expiring leases.
37. COMPLEXITY OF THE OPERATIONS IN SANTOS BASIN
• Distance of about 300 km from the coast
• Huge demand of air and sea
transportation
• Complexity of the gas network
• Operation of 20 own platforms and the
onshore gas processing plant, involving
different partners in 18 platforms
• Wells and platforms with large
production, demanding efficient
surveillance and monitoring
• Operational and environmental risks
• Need for quick and efficient response
to any contingencies
38. FUTURE PETROBRAS OPERATIONS SUPPORT FACILITIES IN SANTOS CITY
• 25,000 m2 of land
• 3 towers for about 2,200 people each
• First tower: occupation in early 2014
39. FUTURE INTEGRATED OPERATIONS CENTER IN SANTOS CITY
in Santos Basin Operations Unit (to be opened: early 2014)
Around 2,900 m2 of the second basement and the 4th floor with another 1,190 m2 area
43. SANTOS BASIN INTEGRATED OPERATIONS CENTER
(Main Solutions to ensure high operational performance)
• Predictive solutions for maintenance and integrity of equipment
(Condition Based Maintenance, Critical Equipment Management
and Monitoring of Electrical Facilities)
• Contingency and Telemedicine
• Operational Support
• Solutions to support the processes integration and predictive
analyses, throughout the surveillance for:
Topside and process plant operations
Well operations
Reservoir geology and engineering
• Integrated Planning and Logistics (IPL)
• Integration of projects implementation
• Collaboration with suppliers and vendors
• Drilling Center
44. CONCLUSION – SANTOS BASIN DEVELOPMENT
A Portfolio of opportunities and challenges
OPPORTUNITIES
• Abundant oil and gas reserves
• A growing oil production and natural gas supply
• Monetizing natural gas
CHALLENGES
• Maximizing scale, standardization and integration (critical
resources) and developing infrastructure and logistics
• Developing new technologies and industry to meet local
content requirements
• Maximizing operational performance