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You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A464 | A discussion covers the three consecutive PROCAP programs. They are the engineering programs that the state owned Petrobras developed with respect to exploitation in ultra deep waters. Five factors that have been decisive for success in the exploitation of petroleum in deep and ultra deep waters in the Campos basin of Brazil are addressed. The present configuration of the program with some details of the program systemics is described. Three of the most difficult technologies to perfect in deep water are considered. The topics relate to the potential of the resources of oil and gas in the deep waters of Brazil; the motivation and focus on the deep waters to extract oil and gas with the success of Petróbras in doing so; the success of Petróbras in deep water exploration as due to its association with industry to resolve all engineering obstacles; the principal achievements of PROCAP as involving the acquisition of FPSO and semi-submersibles technology; PROCAP-3000, launched in June 2000 to discover and exploit fields at 3000 m depth; sub sea system of warm-up of piping and electric pumps; sub sea system to separate water from oil and gas; and conclusions. PROCAP1000, active in 1986-1991, dealt with exploitation at depths of 1000 m. PROCAP-2000, active in 1992-1999, dealt with exploitation in waters of 2000 m depth. The PROCAP-3000 program is active in the period 2000-2005 at depths of 3000 m. The Petróbras installation of the world's first intelligent submarine system, entirely electric, InCharge, installed by Baker Oil Tools is described. Petróbras uses the InCode software of Baker Oil Tools to control well equipment. The installation of InCharge in deep water is the culmination of a 5-yr development project with participation of Baker Oil Tools, Baker Atlas, Petróbras, and QuantX. In December 2002 Petróbras had 11,000 million boe in proven reserves according to SPE methodology. The reserves on land are only 11% of this total. Of the rest, 76% are in waters over 400 m deep and 46% of Petróbas reserves are at depths > 1000 m. The forecast and statistical examination of the production of oil and gas by Petróbras is provided graphically from 1982 to 2002 for flow rates of oil in barrels per day; mixture of production on dry land and at various depths of water in barrels per day of oil since 3/14/2003; and tabulation of the total production of hydrocarbons in various areas of Brazil of LNG, oil, and natural gas from 2000 to 2003. | what is the name of the technology launched in June 2000 to explore fields 3000m deep? | the name of the technology is PROCAP-3000 | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
what is the name of the technology launched in June 2000 to explore fields 3000m deep?
### Response:
the name of the technology is PROCAP-3000 <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1003 | Acoustic monitoring in oceans has grown greatly for several purposes. To meet the needs of an acoustic monitoring program of Petrobras, a Brazilian oil exploration company, an acoustic recorder was developed, called SAASS, an autonomous system for the acquisition of submarine signals. This development had as main goal, the development period and its cost, besides of course, technical requirements for that application. This work has become a very promising experience since it also allowed researches in the area of hydrophone development and acoustic signal analysis methodology. This article will describe the most relevant aspects of the development of SAASS and main strategies adopted to achieve the established objectives of Petrobras program. | What is SAASS? | Autonomous System for the Acquisition of Submarine Signals, an acoustic recorder developed by Petrobras. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is SAASS?
### Response:
Autonomous System for the Acquisition of Submarine Signals, an acoustic recorder developed by Petrobras. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A538 | Acoustic monitoring in oceans has grown greatly for several purposes. To meet the needs of an acoustic monitoring program of Petrobras, a Brazilian oil exploration company, an acoustic recorder was developed, called SAASS, an autonomous system for the acquisition of submarine signals. This development had as main goal, the development period and its cost, besides of course, technical requirements for that application. This work has become a very promising experience since it also allowed researches in the area of hydrophone development and acoustic signal analysis methodology. This article will describe the most relevant aspects of the development of SAASS and main strategies adopted to achieve the established objectives of Petrobras program. | What is SAASS and what was it developed for? | SAASS is an autonomous system for the acquisition of submarine signals. It was developed to meet the needs of an acoustic monitoring program of Petrobras. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is SAASS and what was it developed for?
### Response:
SAASS is an autonomous system for the acquisition of submarine signals. It was developed to meet the needs of an acoustic monitoring program of Petrobras. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A562 | Acoustic monitoring in oceans has grown greatly for several purposes. To meet the needs of an acoustic monitoring program of Petrobras, a Brazilian oil exploration company, an acoustic recorder was developed, called SAASS, an autonomous system for the acquisition of submarine signals. This development had as main goal, the development period and its cost, besides of course, technical requirements for that application. This work has become a very promising experience since it also allowed researches in the area of hydrophone development and acoustic signal analysis methodology. This article will describe the most relevant aspects of the development of SAASS and main strategies adopted to achieve the established objectives of Petrobras program. | What is Petrobras's SAASS? | The autonomous system for the acquisition of submarine signals is an acoustic recorder developed to meet the needs of an acoustic monitoring program in oceans. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is Petrobras's SAASS?
### Response:
The autonomous system for the acquisition of submarine signals is an acoustic recorder developed to meet the needs of an acoustic monitoring program in oceans. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1140 | After the formalization of the base of the Miocene in the Lemme-Carrosio section (Italy) at the base of Subchron C6Cn.2n, the calcareous plankton biostratigraphy was refined in several open ocean Deep Sea Drilling Project/Ocean Drilling Program sites. However, high-resolution quantitative biostratigraphic studies, integrating planktonic foraminifera and calcareous nannofossils, are still lacking for the time interval spanning the Oligocene–Miocene transition. Here, we present a reinvestigation of Deep Sea Drilling Project Hole 516F (Rio Grande Rise) and 4 oil wells drilled by Petróbras Brasileiro SA in the Campos Basin (SW Atlantic Ocean). We identified 12 planktonic foraminiferal and 18 calcareous nannofossil bioevents that have been integrated with an updated magnetostratigraphy of Hole 516F allowing the correlation with the GPTS and the identification of the Oligocene/Miocene boundary (base of Subchron C6Cn.2n) between the Top of Sphenolithus delphix and the Base of common Paragloborotalia kugleri. Furthermore, our results give new insights on the reliability of major calcareous plankton events across the Oligocene–Miocene transition: (a) the Sphenolithus ciperoensis Top, the S. delphix Base and Top, and the Sphenolithus cometa Base are reliable events at a global scale; (b) the Bases of Globoquadrina dehiscens and Sphenolithus disbelemnos > 4 μm are correlatable events only within the study sector of the SW Atlantic Ocean; and (c) the Globoturborotalita ciperoensis Top, Globoturborotalita angulisuturalis Top, and Sphenolithus procerus Base are diachronous. Finally, previously unreported biostratigraphic data, such as the distribution range of S. disbelemnos < 4 μm and Sphenolithus cf. S. pseudoheteromorphus, the Tenuitellinata praestainforthi acme interval, and the Top of common Globigerinoides primordius were identified in the Campos Basin. | Besides the results of the studies generate a better identification of the Oligocene / Miocene limit, they also generated new insights about which events? | Calcareous plankton events across the Oligocene–Miocene | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Besides the results of the studies generate a better identification of the Oligocene / Miocene limit, they also generated new insights about which events?
### Response:
Calcareous plankton events across the Oligocene–Miocene <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A798 | Albacora, a giant field located under water depths ranging from 230m to 1,900m, in Campos Basin, offshore Brazil, has an estimated oil-in-place volume of 4.4 billion bbl and extends over an area of 235 km2. The development plan conceived for this field has been divided into three phases, which the first one is a cost-effective pilot production system, which has started field production in October, 1987. This paper describes many alternatives under study by PETROBRAS for installation of the second phase of the field exploitation. Water depths of the wellheads at this phase will reach 1,166m and the start-up is expected to occur in 1994, with a peak production of nearly 200,000 bopd in 1996. The alternatives differ basically in parameters such as the type (semi-submersible,compliant tower, jacket), quantity, size and location of the production units, the type and configuration of the subsea systems, the type of the production and export risers (rigid, semi-rigid or flexible) and also the level of the infra-structure integration. An economical analysis ends the paper and shows that Phase II, besides of performing a pioneer conception at world level, is also a cost-effective production system. | What is the depth and estimated volume of oil in Albacora? | It has from 230m to 1900m and volume of 4.4 billion bbl | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the depth and estimated volume of oil in Albacora?
### Response:
It has from 230m to 1900m and volume of 4.4 billion bbl <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A953 | An Integrated Operations initiative is on going at Santos Basin in order to face the new challenges of Pre-Salt greenfields. This initiative is being conducted at Petrobras through a corporative plan called GIOp (Integrated Operations Management) and, to potentialize lessons learnt, the company is deploying a pilot in Santos (city located at São Paulo State - Brazil). Petrobras has already tried to apply the smart field concept in previous experiences. The company selected the 20 most interesting processes to be redesigned following the IO concept to run a Pilot in Santos Basin, aiming to test this concept, exercise the collaborative way of working, and acquire experience. This phase used some key available features as tools, temporary collaborative environments and resident professionals. The focus was to obtain early results with a quick wins strategy. Therefore, well and process plant surveillances were implemented for all units of the Santos Basin, followed by a 24/7 Operational Support, which is directly connected to the production units and offshore operations. This paper describes the implementation and execution of the production surveillance activities in Santos Basin, pointing to practical cases of application, across related processes. Many improvement opportunities have been exercised in several disciplines and production assets, in order to incorporate the lessons learnt to the process mapping and bring valuable information for the following phases of the GIOp implementation in Brazil. | where is the pre-salt production surveillance being conducted? | This initiative is being conducted at Petrobras through a corporative plan called GIOp (Integrated Operations Management) | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
where is the pre-salt production surveillance being conducted?
### Response:
This initiative is being conducted at Petrobras through a corporative plan called GIOp (Integrated Operations Management) <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1093 | As a solution for sand production problems associated with the production of hydrocarbons from sandstone reservoirs, the gravel packing technique (GPT) has been used by Petrobras since the early seventies when some small offshore fields in northeast Brazil were completed with this technique. More recently Petrobras has made important discoveries in unconsolidated to friable turbidite sandstones in Campos Basin area, offshore Rio de Janeiro (fig.1). Carapeba, Vermelho and Pargo fields, the so called Northeastern Pole fields (NP fields); and Albacora and Marlim giants fields, located in deep waters, are among these important discoveries. The GPT has been elected as the only sand control technique suitable to those wells. The paper describes Petrobras search for improvement of GPT to suitably complete NP, Albacora and Marlim wells with this technique. The use of the GPT for Albacora and Marlim is unique and is one of Petrobras challenges to deepwater production. | What technique started been used in northeast of Brazil as a solution for sand production during the production of hydrocarbons? | The gravel packing technique, also know as GPT | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What technique started been used in northeast of Brazil as a solution for sand production during the production of hydrocarbons?
### Response:
The gravel packing technique, also know as GPT <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A767 | As a solution for sand production problems associated with the production of hydrocarbons from sandstone reservoirs, the gravel packing technique (GPT) has been used by Petrobras since the early seventies when some small offshore fields in northeast Brazil were completed with this technique. More recently Petrobras has made important discoveries in unconsolidated to friable turbidite sandstones in Campos Basin area, offshore Rio de Janeiro (fig.1). Carapeba, Vermelho and Pargo fields, the so called Northeastern Pole fields (NP fields); and Albacora and Marlim giants fields, located in deep waters, are among these important discoveries. The GPT has been elected as the only sand control technique suitable to those wells. The paper describes Petrobras search for improvement of GPT to suitably complete NP, Albacora and Marlim wells with this technique. The use of the GPT for Albacora and Marlim is unique and is one of Petrobras challenges to deepwater production. | What is the importance of using GPT (Gravel Packing Technique) in the Albacoa and Marlim wells, located in deep waters? | It is a solution for the sand production problems associated with the production of hydrocarbons from sandstone reservoirs | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the importance of using GPT (Gravel Packing Technique) in the Albacoa and Marlim wells, located in deep waters?
### Response:
It is a solution for the sand production problems associated with the production of hydrocarbons from sandstone reservoirs <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A967 | As a solution for sand production problems associated with the production of hydrocarbons from sandstone reservoirs, the gravel packing technique (GPT) has been used by Petrobras since the early seventies when some small offshore fields in northeast Brazil were completed with this technique. More recently Petrobras has made important discoveries in unconsolidated to friable turbidite sandstones in Campos Basin area, offshore Rio de Janeiro (fig.1). Carapeba, Vermelho and Pargo fields, the so called Northeastern Pole fields (NP fields); and Albacora and Marlim giants fields, located in deep waters, are among these important discoveries. The GPT has been elected as the only sand control technique suitable to those wells. The paper describes Petrobras search for improvement of GPT to suitably complete NP, Albacora and Marlim wells with this technique. The use of the GPT for Albacora and Marlim is unique and is one of Petrobras challenges to deepwater production. | What is the main objective of gravel packing technique? | A solution for sand production problems. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the main objective of gravel packing technique?
### Response:
A solution for sand production problems. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1162 | As offshore oil fields are being developed towards deeper and deeper waters, new technologies are required to curb capital expenditures. In Brazil, where oil consumption is increasing and huge oil fields lie in high water depths, the issue is particularly pressing. Earlier and higher oil production from those oil fields could be attained by the use of Electrical Submersible Pumps (ESP), so far restricted to dry completions. Also longer distances from well to platform would be made practical. For the initial phase of this development, Petrobras worked together with Tronic, Reda, Pirelli, Lasalle, Sade-Vigesa and Cooper. As a result, first-in-the-world ESP installation in a subsea well has been successfully achieved on October/1994 in RJS-221, located at Carapeba Field, Campos Basin, Brazil. | With what technology is it possible to increase oil production? | It could be achieved with the use of submersible electric pumps (ESP) | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
With what technology is it possible to increase oil production?
### Response:
It could be achieved with the use of submersible electric pumps (ESP) <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A244 | As offshore oil fields are being developed towards deeper and deeper waters, new technologies are required to curb capital expenditures. In Brazil, where oil consumption is increasing and huge oil fields lie in high water depths, the issue is particularly pressing. Earlier and higher oil production from those oil fields could be attained by the use of Electrical Submersible Pumps (ESP), so far restricted to dry completions. Also longer distances from well to platform would be made practical. For the initial phase of this development, Petrobras worked together with Tronic, Reda, Pirelli, Lasalle, Sade-Vigesa and Cooper. As a result, first-in-the-world ESP installation in a subsea well has been successfully achieved on October/1994 in RJS-221, located at Carapeba Field, Campos Basin, Brazil. | In Brazil, where are the oil fields located? | In high water depths. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
In Brazil, where are the oil fields located?
### Response:
In high water depths. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A484 | As offshore oil fields are being developed towards deeper and deeper waters, new technologies are required to curb capital expenditures. In Brazil, where oil consumption is increasing and huge oil fields lie in high water depths, the issue is particularly pressing. Earlier and higher oil production from those oil fields could be attained by the use of Electrical Submersible Pumps (ESP), so far restricted to dry completions. Also longer distances from well to platform would be made practical. For the initial phase of this development, Petrobras worked together with Tronic, Reda, Pirelli, Lasalle, Sade-Vigesa and Cooper. As a result, first-in-the-world ESP installation in a subsea well has been successfully achieved on October/1994 in RJS-221, located at Carapeba Field, Campos Basin, Brazil. | Which companies contributed with Petrobras in the development of the first installation of Electric Submersible Pump in an underwater well? | Tronic, Reda, Pirelli, Lasalle, Sade-Vigesa and Cooper. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Which companies contributed with Petrobras in the development of the first installation of Electric Submersible Pump in an underwater well?
### Response:
Tronic, Reda, Pirelli, Lasalle, Sade-Vigesa and Cooper. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A500 | As offshore oil fields are being developed towards deeper and deeper waters, new technologies are required to curb capital expenditures. In Brazil, where oil consumption is increasing and huge oil fields lie in high water depths, the issue is particularly pressing. Earlier and higher oil production from those oil fields could be attained by the use of Electrical Submersible Pumps (ESP), so far restricted to dry completions. Also longer distances from well to platform would be made practical. For the initial phase of this development, Petrobras worked together with Tronic, Reda, Pirelli, Lasalle, Sade-Vigesa and Cooper. As a result, first-in-the-world ESP installation in a subsea well has been successfully achieved on October/1994 in RJS-221, located at Carapeba Field, Campos Basin, Brazil. | When did the first installation of an Electric Submersible Pump take place in an underwater well? | October/1994. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
When did the first installation of an Electric Submersible Pump take place in an underwater well?
### Response:
October/1994. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A213 | Based on the knowledge of local artisanal fishermen and on direct observations, this study presents evidence that the giant manta ray Manta birostris uses the Paranaguá estuarine complex in south Brazil, south-western Atlantic Ocean, in a predictable seasonal pattern. Behavioural observations suggest that the estuary can act as a nursery ground for M. birostris during the summer. | When does the giant ray Manta birostris use the Paranaguá estuarine complex in southern Brazil to deposit its eggs? | Summer. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
When does the giant ray Manta birostris use the Paranaguá estuarine complex in southern Brazil to deposit its eggs?
### Response:
Summer. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A725 | BG Group recently produced a new estimate on the Tupi oil discovery in the Santos basin, stating that the field contains 12-30 billion boe or more. On the one hand, Brazil's Petroleo Brasileiro SA (Petrobras) did not comment on the revised production estimate. It can be remembered that Petrobras reported the discovery to be 8 billion bbl of light crude in 2007. Meanwhile, BG claim have been produced in a statement regarding the company's long-term growth strategy, released ahead of the presentation of its fourth-quarter results. | What is the possible cause of the difference in data released by Petrobas and the BG Group on the quantity of barrels? | The BG Group data were released before the fourth quarter results were presented. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the possible cause of the difference in data released by Petrobas and the BG Group on the quantity of barrels?
### Response:
The BG Group data were released before the fourth quarter results were presented. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A929 | BG Group recently produced a new estimate on the Tupi oil discovery in the Santos basin, stating that the field contains 12-30 billion boe or more. On the one hand, Brazil's Petroleo Brasileiro SA (Petrobras) did not comment on the revised production estimate. It can be remembered that Petrobras reported the discovery to be 8 billion bbl of light crude in 2007. Meanwhile, BG claim have been produced in a statement regarding the company's long-term growth strategy, released ahead of the presentation of its fourth-quarter results. | Which field contains 12-30 billion boe or more? | The Santos basin. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Which field contains 12-30 billion boe or more?
### Response:
The Santos basin. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A258 | BR Petrobras plans to spend $224 billion through 2014 to develop deepsea oil finds. Supplying equipment in a timely fashion will be key to its efforts to nearly double oil production in Brazil by 2020. Brazil's government wants the majority of the cash headed to local companies or local units of foreign multinationals and wants to develop the oil services sector, creating industry that could export goods and services around the world. Thus, gradually, the minimum local content requirements will increase up to 95% in 2017. Whoever wishes to have a major role in the E&P will have to establish significant local presence, in particular equipment suppliers (topsides, pipes, drilling packages, power packages for offshore units, etc.), who will likely need to build production facilities in Brazil. The issue is not only to install local manufacturing support, but also pre-sales technical support, a presence close to the shipyards and operators throughout the phase of integration, commissioning and operation, and a very strong and effective after-sale support. The paper will discuss the overall strategy needed to bring to Brazil the technical and manufacturing expertise to support the rapid growth of the shipbuilding industry and will examine the importance of providing local support to the yards and owners to reduce delays in technical proposal and during the construction phase of vessels. Honeywell has set up, in addition of its already existing operations, a Marine operation in Rio de Janeiro. This unit includes: • Front End Engineering Desing (FEED) • Customer Engineering Project Support • Technical sales support • Installation & Commissioning support. • Service Station • Local spare part inventory. Consideration will also be given to a study being run by Honeywell to implement an assembly line in Brazil to minimize logistics costs and delivery times. | How may an assembly line in Brazil be good for a company? | An assembly line has the capability to minimize logistics costs and delivery times. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
How may an assembly line in Brazil be good for a company?
### Response:
An assembly line has the capability to minimize logistics costs and delivery times. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A682 | Brazil has suffered water contamination caused by oil spills, which has caused both short-and long-Term environmental damages. Human error and mechanical problems in offshore equipment during the production, transportation and storage of petroleum constitute the main causes of oil spill. Due to this fact and to emphasize Petrobras' commitment in maintaining and preserving the environment, the company developed strategies and ways to prevent oil spills, as well as methods for controlling them. The result was the construction of Petrobras' Operations Center, which was considered by the president of the company to be an ambitious, innovative and transformative system that enabled Petrobras to make better informed and more efficient operational decisions. This paper aims to share a practical experience on how ICT technologies and digital governance can help both public and private companies to maximize efficiency and profitability in a sustainable way by creating public value and environment-friendly policies. | What is the purpose of the Petrobras Operations Center? | Emphasize the company's commitment to maintaining and preserving the environment through better informed and efficient operational decisions. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the purpose of the Petrobras Operations Center?
### Response:
Emphasize the company's commitment to maintaining and preserving the environment through better informed and efficient operational decisions. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1830 | Brazilian Environmental Authority (IBAMA) adopted EPA rules for discharging drill cuttings from O&G operations. EPA method describes procedures to evaluate toxicity using Leptocheirus plumulosus. Despite being an exotic species, Brazilian laboratories keep L. plumulosus cultures. Otherwise, Grandidierella bonnieroides is widely distributed in Brazilian estuaries is successfully cultured and sensitive to many toxicants. The present study was carried out to evaluate the effects of three non-aqueous drilling fluids (NAF) and two synthetic based drilling muds (SBM) spiked to natural sediment on the amphipods. Reference toxicant experiments were also performed using C16C18 internal olefin or a C16C18 internal olefin SBM of similar density. Sediment was collected in Jabaquara beach, RJ and transferred to the laboratory in chilly bins. After sieving, it was kept at 4 ± 2 °C until spiking for no longer than 60 days. Spiking procedures and whole-sediment tests were set up following the methods described in EPA method 1644 and Brazilian Standards. Amphipods were exposed to 5 concentrations of SBM and NAF spiked sediment plus controls for 4 and 10 days, respectively, in static system. In NAF tests using G. bonnieroides the average LC50 obtained were 3.53 g.kg-1dw (n= 7; SD=1.63; CV= 46.07%), 1.33 g.kg-1dw (n= 6; SD=0.69; CV= 52.15%) and 0.56 g.kg-1dw (n= 7; SD=0.24; CV= 42.69%) for olefin, ester and paraffin, respectively, while L. plumulosus showed an average LC50 of 1.66 g.kg-1dw (n= 6; SD=1.30; CV= 78.10%), 0.60 g.kg-1dw (n= 5; SD=0.22; CV=35.81%) and 0.26 g.kg-1dw (n= 6; SD=0.13; CV= 50.50%), respectively. The average LC50 obtained in SBM 1 (11.6 ppg) tests using G. bonnieroides was 139.78 mL.kg-1dw (n= 3; SD= 69.47; CV= 49.70%) and for SBM 2 (9.9 ppg) the LC50 was 132.97 mL.kg-1dw, while L. plumulosus showed an average LC50 of 94.79 mL.kg-1dw (n= 2; SD= 92.33; CV= 97.41%) LC50 of 34.82 mL.kg-1dw, respectively, for SBM1 and SBM2. In olefin tests using L. plumulosus, SBM 2 test using G. bonnieroides and SBM 1 tests using both species, STR = 1 were obtained, meeting the EPA criteria for drilling cuttings discharge. Although G. bonnieroides has shown to be less sensitive than L. plumulosus to the NAF and SBM, the method using G. bonnieroides as test species demonstrated to be suitable for this purpose and presented similar variability than the same method using L. plumulosus. | IBAMA adopted the EPA rules, which rules have a general purpose? | Describe procedures for evaluating toxicity | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
IBAMA adopted the EPA rules, which rules have a general purpose?
### Response:
Describe procedures for evaluating toxicity <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1700 | Building seismic velocity models honouring complexities evident from seismic data is fundamental to generate inputs for several applications in seismic modeling and imaging. This is particularly important for complex areas, such as the Pre-Salt section of Santos Basin, in the Brazilian offshore. We present a methodology to build velocity models incorporating the geological features identified in legacy seismic data for this basin. Of particular interest is, the internal stratification within the salt section. To characterize a geological layer we propose the use of model-based impedance that combines the geological knowledge from wells and seismic interpretations using rock property relationships. The results are shown in both gathers and stacked migrated sections with improvements in the flattening and the focusing of target reflectors. This approach can also be extended to generate an input velocity model for FWI migration process. | Where are the results of the characterization of the geological layer shown when proposing the use of model-based impedance? | In stacked collection and migration sections with improvements in flattening and focusing of target reflectors. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Where are the results of the characterization of the geological layer shown when proposing the use of model-based impedance?
### Response:
In stacked collection and migration sections with improvements in flattening and focusing of target reflectors. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1701 | Building seismic velocity models honouring complexities evident from seismic data is fundamental to generate inputs for several applications in seismic modeling and imaging. This is particularly important for complex areas, such as the Pre-Salt section of Santos Basin, in the Brazilian offshore. We present a methodology to build velocity models incorporating the geological features identified in legacy seismic data for this basin. Of particular interest is, the internal stratification within the salt section. To characterize a geological layer we propose the use of model-based impedance that combines the geological knowledge from wells and seismic interpretations using rock property relationships. The results are shown in both gathers and stacked migrated sections with improvements in the flattening and the focusing of target reflectors. This approach can also be extended to generate an input velocity model for FWI migration process. | To generate inputs for several applications in seismic modeling and imaging it is essential that? | Build up of seismic velocity models respecting the evident complexities of the seismic data. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
To generate inputs for several applications in seismic modeling and imaging it is essential that?
### Response:
Build up of seismic velocity models respecting the evident complexities of the seismic data. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A232 | By taking a bold step forward in developing the Garoupa field offshore Brazil with subsea techniques, Petroleo Brasileiro SA (Petrobras) will benefit from early production to help satisfy the country's growing energy demand. This article describes the first phase of the development program. Petrobras is seeking a producing rate of 45,000 b/d from nine drilled wells. Wellhead cellars, in which many components, associated connections and well-control systems will be encapsulated, are described along with submarine flow lines, processing and loading, and production and processing control systems. | How will the Brazilian population be benefited with the early production of petroleum? | It will help to supply the growing energy demand. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
How will the Brazilian population be benefited with the early production of petroleum?
### Response:
It will help to supply the growing energy demand. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A780 | By taking a bold step forward in developing the Garoupa field offshore Brazil with subsea techniques, Petroleo Brasileiro SA (Petrobras) will benefit from early production to help satisfy the country's growing energy demand. This article describes the first phase of the development program. Petrobras is seeking a producing rate of 45,000 b/d from nine drilled wells. Wellhead cellars, in which many components, associated connections and well-control systems will be encapsulated, are described along with submarine flow lines, processing and loading, and production and processing control systems. | How will the oil extracted from the Garoupa field by Petrobras be transported? | With submarine flow lines. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
How will the oil extracted from the Garoupa field by Petrobras be transported?
### Response:
With submarine flow lines. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A604 | Construction of the Rio de Janeiro-Sao Paulo gas line for Petrobras represents a landmark within Brazilian energy development since the system interconnects the main South America industrial center located in Sao Paulo state to the Campos basin. This basin, one of the gas and oil offshore producing areas, has the fastest development in the world and is responsible for over 50% of Brazilian oil and natural gas production. This paper discuses the various terrain characteristics, logistics and construction details for this project. | What is produced on the Campos bacin? | oil and natural gas | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is produced on the Campos bacin?
### Response:
oil and natural gas <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1548 | Coquinas constitute widespread deposits in lacustrine, estuarine, and shallow marine settings, where they are a valuable source of information on environmental conditions. Thick coquina successions were deposited in a series of lacustrine rift basins that formed along the Brazilian Continental Margin during the early stages of the opening of the South Atlantic Ocean, in the Early Cretaceous. In the Sergipe-Alagoas Basin, the coquina sequence, equivalent to the Morro do Chaves Formation, crops out in the Atol Quarry, and is considered a relevant analog for the economically important hydrocarbon reservoirs in the Pre-salt strata (Barremian to Aptian) of the Campos Basin (Pampo, Badejo, and Linguado oil fields), which occur only in the subsurface. The aim of this study is to generate a depositional and stratigraphic model through facies and stratigraphic analyses of a well core. These analyses allowed the geological characterization of the Morro do Chaves Formation and of its transition to the adjacent stratigraphic units, the Coqueiro Seco Formation above and the Penedo Formation below, contributing to the growing knowledge of sedimentation in rift basins and exploratory models in hydrocarbon-producing reservoirs. Facies analysis consists of sedimentological, taphonomic, and stratigraphic features of the rocks. Fourteen depositional facies were recognized, stacked into low-frequency and high-frequency, deepening-upward and shallowing-upward cycles driven by the interaction between climate and tectonism. A depositional model is presented, based on the correlation between well-core and outcrop data described in previous studies, providing insights into the spatial distribution of facies. The detailed analysis of facies and stacking patterns sheds light on depositional processes, paleoenvironmental conditions, and the evolution of the system through time, so we may better understand analogous deposits in the geological record. | Where thick coquina were deposited during the early stages of the opening of the South Atlantic Ocean, in the Early Cretaceous? | In a series of lacustrine rift basins that formed along the Brazilian Continental Margin. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Where thick coquina were deposited during the early stages of the opening of the South Atlantic Ocean, in the Early Cretaceous?
### Response:
In a series of lacustrine rift basins that formed along the Brazilian Continental Margin. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1574 | Currently, low oil prices pose a challenge to the financial state of the industry. Therefore, it is very important that companies optimize costs while maintaining or even increasing oil production. At the same time, with oil production declining due high water cuts and facility volume limitations in an offshore production system, it is necessary to look for solutions in order to maintain economic viability by increasing oil recovery in mature reservoirs. Among some alternatives, the subsea separator represents a good prospect for dealing with these challenges. This paper aims to describe a methodology to perform the technical feasibility study of deploying an Oil/Water Subsea Separator in Brazilian Offshore Field. The technical results were then used as part of an economic analysis which is outside the scope of the present paper. The study is comprised four wells that are linked to the manifold and the subsea separator. In the subsea separator, 70% of the produced water is separated and reinjected in a disposal well. Hence, the fluids which remains (oil, gas and 30% of water) flows up to the platform. Since this reinjected water volume is not flowing to the platform anymore, more fluid can be processed, allowing the wells to operate on larger potentials resulting in an increased cumulative oil production to the field. Computational simulation approach was followed by using the pore flow simulation, flow assurance simulation and a coupler that integrates both of these. | How can the subsea separator help increase oil production? | Separating and reinjecting part of the produced water, causing the remaining fluid to rise to the platform and the wells to operate at higher potentials | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
How can the subsea separator help increase oil production?
### Response:
Separating and reinjecting part of the produced water, causing the remaining fluid to rise to the platform and the wells to operate at higher potentials <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1270 | Currently, the Port of Santos is the largest in Latin America, and its access channel is in the process of deepening, intending to reach 17 m DHN as an ultimate goal. Specifically for the maritime bar section, which is now maintained only by dredging, a significant increase in the volume of maintenance dredging is expected. The current study applied the physical modelling to evaluate the effectiveness of two curved jetties in the maintenance of depth along the inlet entrance of Santos channel, its impact on the dispersion of the plume of effluents from the existing outfall and its influence on the beach adjacent to the proposed right jetty. As a result, the jetties’ layout could maintain the access channel’s depth with a much lower volume of dredging than the current maintenance requires. It was found that the increase of 1.2 km on the outfall’s original length would not only reduce the influence of the jetties’ presence, but also improve significantly the dispersion of effluents in comparison to the original situation. Moreover, the presence of the jetties induces a marine accretion that tends to protect the region adjacent to the inlet, which is currently suffering a severe erosion process. Finally, the study shows that it is completely feasible to adopt the curved jetties to transpose the Port of Santos’ maritime bar, which may be configured as an economic and attractive option to maintain depths of 17 m DHN. | What was the conclusion about the study of the curved jetties that was to be implemented at the port of Santos? | the jettie's layout from this study could maintain the access channel's depth with a much lower volume of dredging than the current system. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What was the conclusion about the study of the curved jetties that was to be implemented at the port of Santos?
### Response:
the jettie's layout from this study could maintain the access channel's depth with a much lower volume of dredging than the current system. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1919 | Data presented in this investigation refer to studies integrating palynofacies and organic geochemistry analyses that were performed on 51 samples of PEC-41-SE-9 well, located in the Sergipe Basin, Eastern Brazilian continental margin. It was evaluated the potential for oil generation, identifying the type and degree of maturation of the organic matter. Optical analyzes show that the organic matter is composed in greater proportion by amorphous organic matter in good preservation, with high fluorescence. It also presents a 67% average concerning the total composition of the kerogen. The phytoclasts usually are well preserved in almost all the section. The palynomorphs are composed of an association, predominantly, of spores and pollen grains of genus Classopollis, featuring a predominantly arid to semi-arid climate environment at deposition time. Presence of the dinoflagellate in the upper section displays the first marine ingressions that happened in the end of Aptian. Based on the qualitative and quantitative results of kerogen, it was possible to characterize three distinct palynofacies, in which the palynofacies I had the best features for quality and preservation of organic matter. The results show total organic carbon values up to 6.39% and Rock-Eval pyrolysis data pointed to the type II kerogen rich in organic matter suitable for the formation of hydrocarbon accumulations. The hydrogen index is found between 200 and 550 mg HC/g of total organic carbon, which shows good potential for oil and gas generation. Spore color index data conclude that the organic matter is found predominantly on the immature maturation phase, with SCI values of 4.0 to 4.5, corroborating with data of maximum temperature, of up to 432° C. | What were the conclusions drawn from the qualitative and quantitative results of kerogen? | It was possible to characterize three distinct palynofacies, of which the palynofacies had the best characteristics for quality and preservation of organic matter. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What were the conclusions drawn from the qualitative and quantitative results of kerogen?
### Response:
It was possible to characterize three distinct palynofacies, of which the palynofacies had the best characteristics for quality and preservation of organic matter. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1950 | Deep-sea fans have been proposed to act as carbon sinks, rapid deposition driving shallow methanogenesis to favor net storage within the gas hydrate stability zone (GHSZ). Here, we present new evidence of widespread gas venting from the GHSZ on the upper Amazon deep-sea fan, together with analyses of the first samples of gas hydrates recovered offshore NE Brazil. Multibeam water column and seafloor imagery over an 18,000-km² area of the upper Amazon fan reveal 53 water column gas plumes, rising from venting features in water depths of 650–2600 m. Most gas vents (60%) are located along seafloor faults that record the ongoing gravitational collapse of the fan above deep décollements, while others (40%) are located in water depths of 650–715 m within the upper edge of the GHSZ. Gas compositions from hydrates recovered in vents at three locations on and north of the fan indicate biogenic sources (dominantly methane with 2–15% of CO2; δ¹³C from − 81.1 to − 77.3‰), whereas samples from vents adjacent to the fan proper include possible thermogenic contributions (methane 95%, CO2 4%, and ethane 1%; δ¹³C – 59.2‰). These results concur with previous findings that the upper edge of the GHSZ may be sensitive to temporal changes in water temperatures, but further point to the importance of gas escape from within areas of gas hydrate stability. Our results suggest the role of fluid migration along pathways created by faulting within rapidly deposited passive margin depocenters, which are increasingly recognized to undergo gravitational collapse above décollements. Our findings add to evidence that gas can escape from sediments to the sea in areas where gas hydrates are stable on passive margins, and suggest the need of further studies of the dynamics of deep-sea depocenters in relation to carbon cycling. | What does GHSZ stand for? | gas hydrate stability zone | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What does GHSZ stand for?
### Response:
gas hydrate stability zone <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A688 | Deep-water exploration in Brazil has continued to increase in complexity, requiring new technology to not only meet the ever increasing demands of the challenging environments but also the increase in costs. These have been incurred from the continuous increase and upgrades in safety regulations and the costs associated with exploration into new environments. In this scenario, operators are welcoming any cost-effective methods to evaluate well profitability without sacrificing safety. In a newly discovered potential oil block, it is necessary to obtain downhole data such as pressure, temperature under specific conditions (flow and build-up periods) as well as obtain pressure-compensated fluid samples and produced volume across time. To obtain these data, it is necessary to perform Drill-Stem Tests (DSTs). Using the type of data that can be derived from DSTs, it is possible to estimate the volume of the reservoir, its layers inside the tested field, and other characteristics that are necessary for planning completion. If performed offshore, testing requires safety equipment placed inside the blowout preventer (BOP) stack to keep the well under control, prevent undesired flow, and protect the environment and personnel. Recent discoveries in Brazil indicate that there is a large hydrocarbon potential in the pre-salt area. That area extends in a track that includes 800 kilometers from the northeast to the southern regions, is 200 kilometers wide away from the coast, and has reservoirs that are 3,000 meters deep. The initial estimation of hydrocarbon production for the Brazilian pre-salt area was approximately 60 billion barrels, but other research has shown different results that are estimated to be from 120 to 200 billion barrels. The importance of this information has more than justified the need to perform DST operations to obtain reliable data. According to Petrobras, Brazilian production has increased steadily, and production has been 300 thousand barrels/day since 2008, when pre-salt production in Brazil commenced; the company wants to reach 1 million barrels/day by 2017. To achieve those numbers, it will be necessary to guarantee that the reservoir will respond as originally predicted. This will require acquisition of reliable data to estimate the current resources, which the DST provides. After the DST, if the operator determines that the production from the formation has not performed according to their expectation or their desired production rate, then the operator may choose to fracture the well. This process is performed by injecting large amounts of a specific, proppant-laden fluid into the reservoir at a high pressures and high pump rates, in order to attempt to increase the reservoir's expected production. With the traditionally used equipment, after completing the fracturing process, the equipment must be pulled out of the hole (POOH) and tripped in again to perform the actual drill-stem testing operation. Several trips were required, because the safety equipment available for the oil industry was not certified to work in extreme environments with solids being pumped at high rates and pressures. If the trips were to be consolidated, a specially-designed downhole equipment package would have to be developed. A major engineering/service company has now developed new subsea safety-tree equipment to be placed inside the BOP stack; with this new equipment, the fracturing operation and the drill-stem testing can be performed in the same trip, since the safety valve system has the capability to maintain integrity when functioning in heavy proppant, high pressure, and high pump-rate conditions. This new equipment was qualified for the conditions to which it was expected to be subjected by testing the material behavior under fracturing pressures of up to 13000 psi with 23 bbl/min pumping rate with slurry that had 6 lbm of sand per gallon. After over 350,000 lbm of sand proppant fluid was flowed through the subsea safety tree, and it was closed for 5 minutes at full sand-concentration slurry. Afterwards, the pressure was increased to 15000 psi for 10 minutes with no leakage across the tree. After being disassembled, the new subsea safety tree was inspected; the inspection showed minimal damage and erosion on the inside walls of the tool, indicating that the equipment would qualify for this type of offshore operation. | What are the safety measures used if the Drill-Stem Test is performed on the high seas? | To do this test it is necessary to use safety equipment that is placed inside an explosion preventer, the BOP, in order to keep the well under control | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What are the safety measures used if the Drill-Stem Test is performed on the high seas?
### Response:
To do this test it is necessary to use safety equipment that is placed inside an explosion preventer, the BOP, in order to keep the well under control <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A250 | Deep-water exploration in Brazil has continued to increase in complexity, requiring new technology to not only meet the ever increasing demands of the challenging environments but also the increase in costs. These have been incurred from the continuous increase and upgrades in safety regulations and the costs associated with exploration into new environments. In this scenario, operators are welcoming any cost-effective methods to evaluate well profitability without sacrificing safety. In a newly discovered potential oil block, it is necessary to obtain downhole data such as pressure, temperature under specific conditions (flow and build-up periods) as well as obtain pressure-compensated fluid samples and produced volume across time. To obtain these data, it is necessary to perform Drill-Stem Tests (DSTs). Using the type of data that can be derived from DSTs, it is possible to estimate the volume of the reservoir, its layers inside the tested field, and other characteristics that are necessary for planning completion. If performed offshore, testing requires safety equipment placed inside the blowout preventer (BOP) stack to keep the well under control, prevent undesired flow, and protect the environment and personnel. Recent discoveries in Brazil indicate that there is a large hydrocarbon potential in the pre-salt area. That area extends in a track that includes 800 kilometers from the northeast to the southern regions, is 200 kilometers wide away from the coast, and has reservoirs that are 3,000 meters deep. The initial estimation of hydrocarbon production for the Brazilian pre-salt area was approximately 60 billion barrels, but other research has shown different results that are estimated to be from 120 to 200 billion barrels. The importance of this information has more than justified the need to perform DST operations to obtain reliable data. According to Petrobras, Brazilian production has increased steadily, and production has been 300 thousand barrels/day since 2008, when pre-salt production in Brazil commenced; the company wants to reach 1 million barrels/day by 2017. To achieve those numbers, it will be necessary to guarantee that the reservoir will respond as originally predicted. This will require acquisition of reliable data to estimate the current resources, which the DST provides. After the DST, if the operator determines that the production from the formation has not performed according to their expectation or their desired production rate, then the operator may choose to fracture the well. This process is performed by injecting large amounts of a specific, proppant-laden fluid into the reservoir at a high pressures and high pump rates, in order to attempt to increase the reservoir's expected production. With the traditionally used equipment, after completing the fracturing process, the equipment must be pulled out of the hole (POOH) and tripped in again to perform the actual drill-stem testing operation. Several trips were required, because the safety equipment available for the oil industry was not certified to work in extreme environments with solids being pumped at high rates and pressures. If the trips were to be consolidated, a specially-designed downhole equipment package would have to be developed. A major engineering/service company has now developed new subsea safety-tree equipment to be placed inside the BOP stack; with this new equipment, the fracturing operation and the drill-stem testing can be performed in the same trip, since the safety valve system has the capability to maintain integrity when functioning in heavy proppant, high pressure, and high pump-rate conditions. This new equipment was qualified for the conditions to which it was expected to be subjected by testing the material behavior under fracturing pressures of up to 13000 psi with 23 bbl/min pumping rate with slurry that had 6 lbm of sand per gallon. After over 350,000 lbm of sand proppant fluid was flowed through the subsea safety tree, and it was closed for 5 minutes at full sand-concentration slurry. Afterwards, the pressure was increased to 15000 psi for 10 minutes with no leakage across the tree. After being disassembled, the new subsea safety tree was inspected; the inspection showed minimal damage and erosion on the inside walls of the tool, indicating that the equipment would qualify for this type of offshore operation. | What characteristics are desirable for the challenging environments of deep-water exploration in Brazil? | Cost-effective methods and safety | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What characteristics are desirable for the challenging environments of deep-water exploration in Brazil?
### Response:
Cost-effective methods and safety <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1485 | Diapir piercement through the ocean floor marks the final stages of a dynamic migration path. Once exhumed, a diapir extrudes from the seafloor, placing an obstacle for the flow of ocean bottom currents. While the hydrodynamic response of the flow has been previously studied, the detailed depositional and weathering modifications involved in the piercement process are less understood. To bridge this gap, we gathered already available multibeam bathymetric data, multichannel 2D seismic reflection profiles and collected new single-channel CHIRP profiles, Acoustic Doppler Current Profiler data and sediment samples across Santos Basin, offshore Brazil. In this region, the processes connecting the uppermost subsurface with the lowermost section of the water column are unknown. Data show three main stages of diapir exhumation: pre-, syn- and post-piercement into the seafloor. Extensional faults crown the pre-exposed diapir, before its piercement through the seafloor. Ocean bottom currents rework the top of the faults to form elongated depressions. The bottom currents tightly detour the diapir during and after its exposure at the seafloor. This interaction forms a drift and moat contourite depositional pattern. Our high-resolution data allow relating these morphologies to seafloor processes and distinguishing them from other reflector geometries related to diapir flank deformation, such as outward dipping of reflections. We further use this geometrical distinction to suggest a key for interpreting the exposure versus burial history of other diapirs worldwide. | What are the three main stages of diapir exhumation? | Pre-, syn- and post-piercement into the seafloor. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What are the three main stages of diapir exhumation?
### Response:
Pre-, syn- and post-piercement into the seafloor. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1132 | Drilling salt zones, especially in deep and ultra-deep waters, presents several challenges to be overcome. One of the main problems faced by drilling engineers while designing and executing a section in salt zones, is the formation flow to the wellbore. Temperature and pressure exerted by the rocks above the salt formation make it have a plastic behavior that tend to flow, and close the wellbore caliper as the bit drills it. The deeper the salt formation, the higher the temperature and pressure above it and, consequently, the higher the tendency to flow to the well, causing several problems, such as high torque, drag and stuckpipes. In order to avoid these problems and to keep the wellbore stable, the drilling fluid must exert a minimum hydrostatic pressure on the formation. Thus, the mud weight is a very important parameter that needs to be determined with a good precision. Since there are no reliable tools to help drilling designers to predict the mud weight based on the wellbore information and its lithology, this is a very difficult task. Nowadays, the prediction of mud weights for pre-salt wells is made based on the designer experience and it's updated during the drilling job as the engineers analyze the wellbore behavior. The lack of precision on estimating the correct mud weight causes several operational problems, currently related to high nonproductive times. Petrobras is developing software to predict adequate mud weight in order to avoid salt fluency based on the lithology of the well and a big historic of wells drilled in pre-salt zones. Initial tests show that the software is able to predict the mud weight with a very good precision. This article shows the development of the software and initial results obtained. | What are the causes of the lack of precision on estimating the correct weight of the mud? | Several operational problems, currently related to high nonproductive times. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What are the causes of the lack of precision on estimating the correct weight of the mud?
### Response:
Several operational problems, currently related to high nonproductive times. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1567 | During the last years, a lot of work have been done focusing on development of low shear valves solutions to be applied on petroleum primary process plants. The main goal of the low shear valve is to generate water-in-oil (WiO) and oil-in-water (OiW) emulsions that can be easier treated by the separation process, when compared with emulsion generated by conventional valves. This paper presents experimental results of a comparison between a commercial low shear valve and a conventional valve. Both valves were installedin parallel on a test loop and the fluids used for all test matrix points were potable water mixed with Petrobras Marlim Crude Oil. The test matrix includes variation of differential pressure on valves, flowrates and concentration of water/oil. Samples were collected downstream of both valves and led to settle into several residence times. The degree of contamination of both phases were analyzed for all residence times. The benefit of the application of low shear valve was quantified for all test conditions and the results were very promissory. The pressure drops across valves were selected considering typical values observed at Petrobras choke valves and control level valves. For almost all test matrix's points the emulsion generated by the low shear valve showed at least a slight benefit, allowing have better water quality after settling. The low shear valve solution showed to be a promissory technology but the magnitude of the benefit is very influenced by valve process operation conditions. | What was the result of the low shear valve test? | It had at least a slight benefit, allowing for better water quality after sedimentation. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What was the result of the low shear valve test?
### Response:
It had at least a slight benefit, allowing for better water quality after sedimentation. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1873 | Fatigue is one of the key governing conditions in the design of rigid risers, in particular those in ultra-deep water. One effective way of improving fatigue is to adopt a lazy wave configuration, rather than a simple catenary. Steel Lazy Wave Risers (SLWR) have been successfully used offshore Brazil (Hoffman et al. 2010, Oliveira et al. 2017) and in the Gulf of Mexico (Beattie et al. 2013), and have been considered for the North Sea (Felista et al. 2015) and offshore Australia (Vijayaraghavan et al. 2015). Yet, it is probably the most computational-intensive aspect of it. Fatigue analyses require a very large number of load cases to be run, on complex, non-linear models. Methods for simplifying aspects of the analysis are highly desirable, but they must be weighed to provide the required safety levels whilst not introducing uneconomical, overconservative assumptions. The top first weld is a crucial hotspot, in particular for production SLWRs (Senra et al. 2011). These typically adopt flexible joints (FJ) at the connection to the vessel/platform, and linearization of the FJ stiffness is one of these key simplifications that bring significant value in reducing analysis cost. This paper describes a method for estimating the characteristic angle used for the linearization, which results in significant stiffness reduction in contrast with the usual, simpler method. Non-linear FJ stiffness curves are usually available, and they provide stiffness associated to the FJ absolute angle. The FJ stiffness significantly reduces with the angle of rotation. The conventional method adopts the stiffness corresponding to the most likely riser angle - absolute value measured from the static configuration. Conversely, the proposed methodology for estimating the most likely change in angle. As the angles often turn up in alternate angles, the proposed method results in much higher characteristic angle, and hence much lower FJ stiffness. The outcome is significantly less conservative designs, whilst still meeting the same required safety margins. | What is the duality regarding the benefits of Steel Lazy Wave Risers (SLWR)? | This is effective in improving fatigue and adopting a slow wave configuration, instead of a simple catenary. SLWRs have been used successfully in Brazil, the Gulf of Mexico, the North Sea and Australia. However, it is probably the most computationally intensive aspect of it. Fatigue analysis requires a large number of load cases to be performed, in complex nonlinear models. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the duality regarding the benefits of Steel Lazy Wave Risers (SLWR)?
### Response:
This is effective in improving fatigue and adopting a slow wave configuration, instead of a simple catenary. SLWRs have been used successfully in Brazil, the Gulf of Mexico, the North Sea and Australia. However, it is probably the most computationally intensive aspect of it. Fatigue analysis requires a large number of load cases to be performed, in complex nonlinear models. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1241 | Fifty-nine length-weight (LWR) and length-length (LLR) relationships were estimated for 18 fish species, belonging to 10 families. The fish specimens were captured in rockpools of 21 sites along a stretch of 4,900 km of the Brazilian coast, between latitudes 00° and 22°S, in 2012. This study represents the first reference available for five fish species (Gobiesox barbatulus, Bathygobius geminatus, Labrisomus nuchipinnis, Malacoctenus delalandii, Lutjanus alexandrei) in LLR and six (Gobiesox barbatulus, Bathygobius geminatus, Hypleurochilus fissicornis, Omobranchus punctatus, Entomacrodus vomerinus, Diplodus argenteus) in LWR. | What species the study referenced in length-length (LLR) relationships? | Gobiesox barbatulus, Bathygobius geminatus, Labrisomus nuchipinnis, Malacoctenus delalandii, Lutjanus alexandrei | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What species the study referenced in length-length (LLR) relationships?
### Response:
Gobiesox barbatulus, Bathygobius geminatus, Labrisomus nuchipinnis, Malacoctenus delalandii, Lutjanus alexandrei <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A171 | Fish fauna was studied in five sites of the shallow infralittoral of the Paranaguá Bay during the period from October 1999 to September 2000. At each sampling site, fish were sampled with other trawls, salinity and temperature were measured, water samples were taken from the bottom of the water column for determination of dissolved oxygen, dissolved inorganic nitrogen and phosphate. The spatial and temporal behavior of the environmental variables was analyzed by a Principal Component Analysis; Cluster Analysis was used to gather the sampling sites, and Factorial Correspondence Analysis was applied to the most abundant species. Temperature was the most important variable for the distribution of the months, allowing the division of the study period into hot and cold months. The temporal variation in the fish fauna composition was indicated by cluster analysis, with highest percentages of dissimilarity between the sampling sites during hot months. The variation in dissimilarity between the sites occurred due to differences in the number of individuals and species of the catches. The high frequencies of occurrence of Anisotremus surinamensis, Etropus crossotus, Genidens genidens, Micropogonias furnieri and Sphoeroides greeleyi were related to high temperatures. The greatest number of fish and species observed in hot months may be related to the life cycle of many species, which reproduce in warmer months, and whose offspring use estuaries as breeding areas. | What is the reason for the high frequency of occurrence of Anisotremus surinamensis, Etropus crossotus, Genidens genidens, Micropogonias furnieri and Sphoeroides greeleyi in the shallow infralittoral of the Paranaguá Bay? | The reason is related to high temperatures. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the reason for the high frequency of occurrence of Anisotremus surinamensis, Etropus crossotus, Genidens genidens, Micropogonias furnieri and Sphoeroides greeleyi in the shallow infralittoral of the Paranaguá Bay?
### Response:
The reason is related to high temperatures. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1090 | Forty-four companies competed for 23 blocks - 13 offshore and 10 onshore - in Brazil's second bid round in June 2000. That 21 of the 23 blocks on offer were licensed shows that the country remains a big draw among E&P firms. The top bidders include a consortium between Santa Fe Snyder (operator, 45%) and Construtora Norberto Odebrecht (15%), which paid 12.025 million real ($6.68 million) for Block BM-C-8 in the Campos basin; Shell, which offered 65.16 million real for the hotly contested Campos Block BM-C-10, for which it was the sole bidder; and Petrobras, with eight winning bids. | The article alludes to the fact that Brazil is still a hotspot for oil exploration, which factor led to this conclusion? | The fact that big firms of E&P participated on the auction for the blocks | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
The article alludes to the fact that Brazil is still a hotspot for oil exploration, which factor led to this conclusion?
### Response:
The fact that big firms of E&P participated on the auction for the blocks <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1083 | Forty-four companies competed for 23 blocks - 13 offshore and 10 onshore - in Brazil's second bid round in June 2000. That 21 of the 23 blocks on offer were licensed shows that the country remains a big draw among E&P firms. The top bidders include a consortium between Santa Fe Snyder (operator, 45%) and Construtora Norberto Odebrecht (15%), which paid 12.025 million real ($6.68 million) for Block BM-C-8 in the Campos basin; Shell, which offered 65.16 million real for the hotly contested Campos Block BM-C-10, for which it was the sole bidder; and Petrobras, with eight winning bids. | One particular block called more attention than the others even though there was only one bidder. Who was this bidder and what was the block called? | The bidder was Shell and the block was Campos | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
One particular block called more attention than the others even though there was only one bidder. Who was this bidder and what was the block called?
### Response:
The bidder was Shell and the block was Campos <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1842 | Geologic events related to the opening of the South Atlantic Ocean deeply influenced the sedimentary record of the Araripe Basin. As consequence, upper stratigraphic units of the basin record a marine ingression in northeastern Brazil during the late Aptian. The timing and stratigraphic architecture of these units are crucial to understand the paleogeography of Gondwana and how the proto-Atlantic Ocean reached interior NE Brazil during the early Cretaceous. This marine ingression is recorded in the Araripe Basin as the Romualdo Formation, characterized by a transgressive-regressive cycle bounded by two regional unconformities. In the eastern part of the basin, the Romualdo depositional sequence comprises coastal alluvial and tide-dominated deposits followed by marine transgressive facies characterized by two fossil-rich intervals: a lower interval of black shales with fossil-rich carbonate concretions (Konservat-Lagerstätten) and an upper level with mollusk-dominated shell beds and shelly limestones. Following the marine ingression, an incomplete regressive succession of marginal-marine facies records the return of continental environments to the basin. The stratigraphic framework based on the correlation of several sections defines a transgressive-regressive cycle with depositional dip towards southeast, decreasing in thickness towards northwest, and with source areas located at the northern side of the basin. The facies-cycle wedge-geometry, together with paleocurrent data, indicates a coastal onlap towards NNW. Therefore, contrary to several paleogeographic scenarios previously proposed, the marine ingression would have reached the western parts of the Araripe Basin from the SSE. | What geological phenomenon recorded the return of continental environments to the Araripe basin? | The incomplete regressive succession of marginal marine facies. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What geological phenomenon recorded the return of continental environments to the Araripe basin?
### Response:
The incomplete regressive succession of marginal marine facies. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1851 | Geologic events related to the opening of the South Atlantic Ocean deeply influenced the sedimentary record of the Araripe Basin. As consequence, upper stratigraphic units of the basin record a marine ingression in northeastern Brazil during the late Aptian. The timing and stratigraphic architecture of these units are crucial to understand the paleogeography of Gondwana and how the proto-Atlantic Ocean reached interior NE Brazil during the early Cretaceous. This marine ingression is recorded in the Araripe Basin as the Romualdo Formation, characterized by a transgressive-regressive cycle bounded by two regional unconformities. In the eastern part of the basin, the Romualdo depositional sequence comprises coastal alluvial and tide-dominated deposits followed by marine transgressive facies characterized by two fossil-rich intervals: a lower interval of black shales with fossil-rich carbonate concretions (Konservat-Lagerstätten) and an upper level with mollusk-dominated shell beds and shelly limestones. Following the marine ingression, an incomplete regressive succession of marginal-marine facies records the return of continental environments to the basin. The stratigraphic framework based on the correlation of several sections defines a transgressive-regressive cycle with depositional dip towards southeast, decreasing in thickness towards northwest, and with source areas located at the northern side of the basin. The facies-cycle wedge-geometry, together with paleocurrent data, indicates a coastal onlap towards NNW. Therefore, contrary to several paleogeographic scenarios previously proposed, the marine ingression would have reached the western parts of the Araripe Basin from the SSE. | What are the characteristics of the marine facies in the eastern part of the Araripe Basin? | By a lower level of black shales with fossil-rich carbonate concretions and an upper level with mollusk-dominated shell beds and shelly limestones. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What are the characteristics of the marine facies in the eastern part of the Araripe Basin?
### Response:
By a lower level of black shales with fossil-rich carbonate concretions and an upper level with mollusk-dominated shell beds and shelly limestones. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1951 | Given the importance of copepods in pelagic food webs, short- and medium-scale temporal variation in the distribution and abundance of copepods of the genus Pseudodiaptomus was investigated in an oligo-mesohaline estuary (Paracauari) in northern Brazil. This system is characterized by high local hydrodynamics and nutrient input from the Paracauari River and Marajo Bay, and marked seasonal variation in rainfall levels. The temporal variation in the abundance of copepods was analyzed in the context of some hydrological variables tide height, salinity, temperature, pH, and concentrations of suspended particulate material, dissolved oxygen and chlorophylla. Samples were collected in 2009 at a fixed station (00° 44'15.4 '' S, 48° 31'07.5 '' W) every 3 hours during a nycthemeral cycle in the neap and spring tides of February, May, June, August, November, and December. Zooplankton samples were collected using horizontal hauls of plankton nets with a 120 pm mesh. Following identification, the abundance and density of Pseudodiaptomus copepods were determined. Data were analyzed using an ANOVA (to assess the significance of diurnal, fortnightly and seasonal variations), PCA, and Bray-Curtis similarity. Four species were identified: Pseudodiaptomus richardi, Pseudodiaptomus marshi, Pseudodiaptomus gracilis, and Pseudodiaptomus acutus. The results indicate that variation in composition and density of the Pseudodiaptomidae copepods in the Paracauari estuary is determined by the interactive effect of the freshwater influx from Marajo Bay, tides, and the rainfall regimen, which modulate local salinity. The absence of diurnal variation in species composition and density was determined by the high local hydrodynamics, which provoke the constant mixing of the estuary's water. | How is Paracuari's oligo-mesohaline estuary characterized? | by high local hydrodynamics and nutrient input from the Paracauari River and Marajó Bay | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
How is Paracuari's oligo-mesohaline estuary characterized?
### Response:
by high local hydrodynamics and nutrient input from the Paracauari River and Marajó Bay <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1952 | Given the importance of copepods in pelagic food webs, short- and medium-scale temporal variation in the distribution and abundance of copepods of the genus Pseudodiaptomus was investigated in an oligo-mesohaline estuary (Paracauari) in northern Brazil. This system is characterized by high local hydrodynamics and nutrient input from the Paracauari River and Marajo Bay, and marked seasonal variation in rainfall levels. The temporal variation in the abundance of copepods was analyzed in the context of some hydrological variables tide height, salinity, temperature, pH, and concentrations of suspended particulate material, dissolved oxygen and chlorophylla. Samples were collected in 2009 at a fixed station (00° 44'15.4 '' S, 48° 31'07.5 '' W) every 3 hours during a nycthemeral cycle in the neap and spring tides of February, May, June, August, November, and December. Zooplankton samples were collected using horizontal hauls of plankton nets with a 120 pm mesh. Following identification, the abundance and density of Pseudodiaptomus copepods were determined. Data were analyzed using an ANOVA (to assess the significance of diurnal, fortnightly and seasonal variations), PCA, and Bray-Curtis similarity. Four species were identified: Pseudodiaptomus richardi, Pseudodiaptomus marshi, Pseudodiaptomus gracilis, and Pseudodiaptomus acutus. The results indicate that variation in composition and density of the Pseudodiaptomidae copepods in the Paracauari estuary is determined by the interactive effect of the freshwater influx from Marajo Bay, tides, and the rainfall regimen, which modulate local salinity. The absence of diurnal variation in species composition and density was determined by the high local hydrodynamics, which provoke the constant mixing of the estuary's water. | What does the high local hydrodynamics provoke? | the constant mixing of the estuary's water | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What does the high local hydrodynamics provoke?
### Response:
the constant mixing of the estuary's water <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A371 | Hamworthy has supplied its first onboard LNG regasification plant - the first of four such installations due delivery from the supplier. Hamworthy delivered an onboard vaporizer system to be installed on the 145,000 cu m LNG shuttle regasification vessel (SRV) Suez Neptune. SRV are designed to transport and store LNG, and then vaporize it into natural gas that can be sent ashore by subsea pipeline. Hamworthy is supplying three regasification skids per ship. Each shipset will have a regasification capacity of 210 ton/hr of LNG with a send-out pressure of 115 bar. The firm's second project comprises plant for a 138,000 cu m LNG floating storage and regasification unit, Golar Winter. The vessel will be chartered by Petrobras in an LNG import project located in Guanabara Bay, Brazil, where gas will be sent from the vessel to an onshore gas grid. | On which vessel will the Hamworthy vaporizer system be installed? | Suez Neptune. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
On which vessel will the Hamworthy vaporizer system be installed?
### Response:
Suez Neptune. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1796 | Igneous rocks are widely developed in many hydrocarbon-bearing sedimentary basins in Brazil, and some igneous rocks play positive roles in the oil and gas accumulation process. But so far, no industrial oil or gas flow is discovered in igneous rocks in Brazilian onshore basins. At present, in some literatures published by some researchers, cases of igneous reservoirs in Brazil are inaccurate. The lithology of reservoirs in the Igarape Cuia oil and gas field, the oil and gas field of Urucu and the Barra Bonita gasfield, were previously thought to be volcanic rocks, but now are clastic rocks according to studies, and the igneous rocks in these three oil and gas field can only be acted as indirect and direct cap rocks. Furthermore, igneous rock reservoirs in the Campos Basin and Santos Basin in the Brazilian offshore are briefly analyzed. The representative Badejo oilfield in the Campos Basin has igneous rock reservoirs dominated by basalts which are intercalated with thin layers of volcaniclastic and sedimentary rocks, the storage space are vesicules, fractures and vugular pores, and the porosity of hydrocarbon bearing interval basalt reservoirs ranges from 10% to 15%. In addition, for the Santos Basin, igneous rocks in this basin are dominated by basic rocks, some alkaline intrusive rocks develop good micro spaces, mainly crystal moldic pores, inter- and intra-crystal dissolution pores and fractures, better reservoir intervals are often concentrated such as at sections near to unconformity surfaces and can have porosity of 6%–9% or higher; local pre-salt igneous rock reservoirs in the Santos Basin have the necessary conditions for hydrocarbon accumulation and it will be a new target layer for hydrocarbon exploration. | The Badejo oil field, which is representative in the Campos Basin, has predominantly kind of rock? | It has reservoirs of igneous rock dominated by basalts that are interspersed with thin layers of volcaniclastic and sedimentary rocks. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
The Badejo oil field, which is representative in the Campos Basin, has predominantly kind of rock?
### Response:
It has reservoirs of igneous rock dominated by basalts that are interspersed with thin layers of volcaniclastic and sedimentary rocks. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A888 | In 1939, the Lobito oil field, Brazil's first, was discovered. During the 1950's, 15 significant fields were discovered. In 1975, the exclusion of private capital in Brazilian oil operations came to an abrupt end. Petrobras was authorized to seek service contracts with foreign oil companies in regions not under exploration. The Campos basin is the most productive oil province in Brazil, accounting for about 62% of current production. The Campos basin is an Atlantic-type basin, typical of a passive continental margin. | What is the most productive oil province in Brazil? | The Campos basin. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the most productive oil province in Brazil?
### Response:
The Campos basin. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A366 | In 1939, the Lobito oil field, Brazil's first, was discovered. During the 1950's, 15 significant fields were discovered. In 1975, the exclusion of private capital in Brazilian oil operations came to an abrupt end. Petrobras was authorized to seek service contracts with foreign oil companies in regions not under exploration. The Campos basin is the most productive oil province in Brazil, accounting for about 62% of current production. The Campos basin is an Atlantic-type basin, typical of a passive continental margin. | What percentage of the current Brazilian oil production does the Campos basin correspond to? | 62%. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What percentage of the current Brazilian oil production does the Campos basin correspond to?
### Response:
62%. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A536 | In 1998, Petrobras installed the first steel catenary riser on a P-18 semi-submersible platform, in Marlim Field, at 910 m water depth. It was decided to install a monitoring system to check the riser design methodology, including Vortex Induced Vibrations (VIV) Analysis. For VIV monitoring, the riser was instrumented with bottles with sophisticated accelerometers in different points, to measure accelerations at a rate of 2 Hz for 300 seconds every 3 hours. The other monitoring systems installed are the oceanographic buoy, to measure waves (height, period and direction), surface current (value and direction), wind, pressures, etc. and Acoustic Doppler Current Profiles (ADCP) to measure instantaneously the current (velocity and direction) along the water column. There is a positioning system (PETRONAV) consisting of GPS receiver with phase correction blended with inertial sensors by a Kalman Filter to measure platform precise absolute positions and movements. All these systems are synchronized to acquire data at the same period of time, to make possible the reanalysis with more reality. This paper describes the VIV monitoring system, including some eletronical system description and the methodology used to define the water depth of each bottle. | Apart from Riser, what other monitoring systems are installed? | The other monitoring systems are the oceanographic buoy and acoustic Doppler current profiles | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Apart from Riser, what other monitoring systems are installed?
### Response:
The other monitoring systems are the oceanographic buoy and acoustic Doppler current profiles <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A968 | In 2004, after a cycle of 11 yr in which the annual increase in crude oil production was 8.6% avg, the production decreased 3%, according to Petrobras. In 2003, the production was 1.54 million bpd avg. The decline in production was due to delays in construction and the arrival of two Floating Production Storage Offloading vessels, the P-43 and P-48. The P-43 began to process crude oil on 12/22/2004. When the P-48 enters service, Petrobras will be able to increase its production of crude oil by 500,000 bpd. The P-43 is stationed in the Barracuda field, bay of Campos, offshore the state of Rio de Janeiro, in 800 m of water. Initial oil yield is 10,380 bpd of 25° gravity. Platform P-48, the twin of P-43, is part of the Barracuda-Caratinga project that will increase Petrobras crude oil production by 300,000 bpd. This platform will enter service in January 2005. With the new capacity, the production of crude oil by Petrobras is expected to reach 1.9 million bpd by the end of 2005. Other floating installations will contribute as well when they enter service, the P-50 and P-34. Petrobras is to invest $26,200 million until 2010 for E&P. Between 2005 and 2008, 17 installations will enter service allowing annual increases of 5.9% in production of crude oil and NGL, achieving self sufficiency in 2006. Petrobras has invested heavily in improved recovery that in the last 10 yr in the Marlim oilfield has yielded an additional increment of 3000 million bbl of crude oil. In November 2004 Petrobras gave a $47 million contract to the Western Geco company to make a three dimensional seismic study of the Marlim basin to identify reserves there. Discovery of an additional 290 million bbl of crude oil in Marlim is expected. On dry land, improved recovery enabled an increment of 200,000 bpd in production from the fields in the states of Bahia, Rio Grande do Norte, and Sergipe in 2004. In 2006-2007, the company expects to substitute for imports of light crude oil its own production to start in the oilfield offshore the state of Espírito Santo. This is lighter crude oil than that from the bay of Campos where the company now obtains 80% of its oil production. The Brazilian oilfields produce mainly heavy crude oil that has to be mixed with lighter imported crude oil to produce quality gasoline. However, Brazil increases its exports of heavy crude oil. The company is involved in new areas of exploration. They are discussed. The Brazilian Petroleum Authority, Agencia Nacional de Petroleo, will likely hold the 7th hydrocarbon licensing round for concessions in crude oil E&P in October 2005. | What is the name of the bay that Barracuda field is located in? | Campos | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the name of the bay that Barracuda field is located in?
### Response:
Campos <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1098 | In a scenario of huge investments in the quest for new oil and natural gas discoveries, the oil industry has reached a consensus: no easy fields to be developed remain undiscovered, especially in offshore environments. New and old challenges on well drilling such as drilled extensions over 6000 m, sub-salt drilling, very narrow operational windows, operational problems like lost of circulation, stuck pipe, and kicks are aggravated when drilling in high pressure and high temperature (HPHT) environments. In the world's exploratory context, the occurrence of HPHT areas is an increasing trend. It is the materialization of the worst case scenario for well drilling and safety, formed by great challenges and operational, environmental, and economic risks. Field experience has shown that the economical risks have been overshadowed by the great premium target: increments on reserves. However, if the well safety aspect is dealt with the conventional approach, the oil industry is at risk of losing its investments, causing great impacts to the environment and also to the company's image. Since HPHT well construction costs are so much higher than those of traditional wells, the scope of knowledge and science on well safety, once limited to kick prevention and well control contingencies, are now an integral part of the technical and economic feasibility of well construction. Within this context, this work surveys the best HPHT techniques and procedures practiced by the oil industry, presents the new researches and trends and shares some valuable lessons learned on Petrobras' operations in Brazil and throughout the world. | What is the consensus that the oil industry has reached about the new oil and gas discoveries? | That there are no easy fields to be developed remain undiscovered, especially in offshore environments | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the consensus that the oil industry has reached about the new oil and gas discoveries?
### Response:
That there are no easy fields to be developed remain undiscovered, especially in offshore environments <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1399 | In Brazil, environmental laws define oil containment and collection as a primary strategy to oil spills originated by exploitation and production enterprises that reaches water bodies. Thus, it is foreseen a continuous equipment increase over the time, in a scaled response, always in accordance to accidental scenarios forecasted in the enterprise risk assessment. This way, minor spills, with higher probability to occur, require smaller resources, however made available in a smaller rage of time, whereas larger and less frequent spills must be attended to with strongest resources, in a larger period of time. At Brazilian maritime zones with higher exploitation and production activities the use of larger vessels, aiming to solve the worst cases, was prioritizred. Such vessels are also used to respond the small and medium discharges, which could be solved by less robust vessels. The use of smaller and fastest vessels and simpler equipment to be operated allows the fleet's rationalization and a quicker and more effective response to more frequent situations. This changing also fosters economic profits (by reducing the figures and the fees paid by vessels chartering) and environmental benefits (by reducing emissions and the fuel consumption). In order to represent this situation, this paper compares the compliance with requirements from regulatory agency using an exclusive fleet of traditional boats and a fleet of traditional boats and fast response. A case study will be presented, considering a high activity oilfield on Brazilian coast. | Which primary strategy to oil spills originated by exploitation is defined by environmental laws in Brazil? | Oil containment and collection | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Which primary strategy to oil spills originated by exploitation is defined by environmental laws in Brazil?
### Response:
Oil containment and collection <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A610 | In the 90's, after success in drilling wells deeper than 5,000 meters with high production rates between 80 to 120 MMSCFD of production, Petrobras decided to continuously measure pressure on their high productivity wells (7" production tubing) because of the difficulty they experienced when running gauges in the production mode after the wells were completed. Therefore, the decision was made to use permanent electronic gauges to obtain downhole pressure as it was a proven technology and optical sensing technology (fiber optics) was new to the industry. At that time, four wells in the San Antonio and San Alberto fields were completed with electronic gauges with different results....one did not work, one failed at the beginning, one failed months later, and one worked intermittently. Petrobras' objective to have real time downhole pressure did not change, and they planned for the next workovers of their wells to use optical sensing technology instead of electronic gauges. These specifications were required on their next bid, and the four wells were assigned to Weatherford International. Since that time, this technology is working in the four wells in the San Antonio and San Alberto fields, and there have only been small problems on surface equipment connections, which were corrected promptly. Because of this success, Petrobras decided last year to implement optical sensing technology in all of their new wells because it was the only proven technology that could support the high vibration, produced by the 7'' tubing wells, and high temperature. The decision was taken one step further to install fiber optic downhole flowmeters on the intelligent completion wells. The use of this technology, complemented with the online PanSystem™ well test analysis software, enables real time well testing. | What made Petrobras decide to implement optical sensing technology in all of its new wells? | The recent success it saw in switching from electronic gauges to optical sensing technology on the workovers of its wells. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What made Petrobras decide to implement optical sensing technology in all of its new wells?
### Response:
The recent success it saw in switching from electronic gauges to optical sensing technology on the workovers of its wells. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1689 | In the context of the Doce river (Southeast Brazil) Fundão dam disaster in 2015, we monitored the changes in concentrations of metal(loid)s in water and sediment and their particulate and dissolved partitioning over time. Samples were collected before, during, and after the mine tailings arrival to the Doce river estuary (pre-impact: 12, 10, 3 and 1 day; acute stage: tailing day - TD and 1 day after - DA; chronic stage: 3 months and 1 year post-disaster). Our results show that metal(loid) concentrations significantly increased with time after the disaster and changed their chemical partitioning in the water. 35.2 mg Fe L-1 and 14.4 mg Al L-1 were observed in the total (unfiltered) water during the acute stage, while aqueous Al, As, Cd, Cr, Cu, Fe, Mn, Ni, Pb, Se and Zn concentrations all exceeded both Brazilian and international safe levels for water quality. The Al, Fe and Pb partitioning coefficient log (Kd) decrease in the acute stage could be related to the high colloid content in the tailings. We continued to observe high concentrations for Al, Ba, Cd, Cr, Cu, Fe, V and Zn mainly in the particulate fraction during the chronic stage. Furthermore, the Doce river estuary had been previously contaminated by As, Ba, Cr, Cu, Mn, Ni and Pb, with a further increase in sediment through the tailing release (e.g. 9-fold increase for Cr, from 3.61 ± 2.19 μg g-1 in the pre-impact to 32.16 ± 20.94 μg·g-1 in the chronic stage). Doce river sediments and original tailing samples were similar in metal(loid) composition for Al, As, Cd, Cr, Cu, Fe, V and Zn. As a result, these elements could be used as geochemical markers of the Fundão tailings and considering other key parameters to define a baseline for monitoring the impacts of this environmental disaster. | Which elements had a higher than safe levels of concetration while in their aqueous state on water quality for both Brazil and international parties? | Al, As, Cd, Cr, Cu, Fe, Mn, Ni, Pb, Se and Zn | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Which elements had a higher than safe levels of concetration while in their aqueous state on water quality for both Brazil and international parties?
### Response:
Al, As, Cd, Cr, Cu, Fe, Mn, Ni, Pb, Se and Zn <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1933 | In the Peregrino field, located in the Campos Basin offshore Brazil, the operator adopted the use of water-based drilling fluids for drilling development wells due to rig limitations. In the 12 ¼-in. sections of several wells drilled in this field, high dispersion of shale minerals suffered by the drilling fluid caused increments of viscosity, which subsequently affected the drilling process through higher-than-expected circulation pressures, dilution rates, and costs. Although the wells have been drilled within the estimated times and budgets, an improvement in the fluid inhibition capability was initiated. A detailed laboratory effort was conducted to obtain a combination of inhibitors capable of controlling excessive clay dispersion, minimizing fluid rock interaction, and reducing dilution requirements while helping to ensure an adequate rheological profile throughout the interval. Laboratory validation of the interaction between the fluid and rock samples provided a better understanding of the inhibition mechanisms and helped ensure that stability of the reactive minerals drilled could be maintained. Various additives were tested against samples of commercial-reactive and field-reactive clays. Product concentrations were adjusted to reduce the interaction between the drilling fluid and the formation while helping to ensure that fluid capabilities, such as cuttings suspension, filtration control, and bridging, were maintained. An adequate environmental profile to enable safe disposal of fluid in compliance with local environmental regulations was also obtained. After identifying an adequate solution, a detailed utilization plan was developed and put in place. To aid proper deployment while drilling, specific mixing procedures at the support liquid mud plant, transportation vessels, and at the rig site were determined. The next step was to assign a candidate well for the application - an Extended Reach Well (ERW) with step-out ratio of 2.9. While drilling the 12-¼-in. section of the pilot well with the proposed fluid technology, a significant improvement was observed on cuttings integrity, which led to a reduction in the required volume of dilution and a subsequent drilling fluids cost reduction Also, better hole quality and reduced operational risks were obtained. The well was safely drilled with a 76° sail inclination, 7938 meters of Measured Depth (MD) and 2368 meters of True Vertical Depth (TVD), and lessons learned from the first utilization of the described fluid system were implemented on subsequent wells to continue obtaining the benefits of the new fluid formulation. High Performance Water Based Drilling Fluids (HPWBDF) are not new and are thought by most to be a mature technology. However, advancements in water-based drilling fluid additives have enabled these systems to mimic the performance of non-aqueous systems more closely. This paper discusses how understanding the chemistry of the formations to be drilled and customizing chemical additive blends for those formations can help to improve operational efficiency and minimize costs. | What steps were taken to develop and utilize the water-based drilling fluid? | Laboratory research, development of an utilization plan, assignment of a drilling well, and drilling testing. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What steps were taken to develop and utilize the water-based drilling fluid?
### Response:
Laboratory research, development of an utilization plan, assignment of a drilling well, and drilling testing. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1186 | In the Santos basin off Brazil, Petrobras ran numerical simulations to evaluate the creep behavior of salt rocks (halite, carnallite, and tachyhydrite) at high differential stress and high temperature, using finite-element codes developed in-house. The results were used to predict the evolution of the well closure over time for various drilling fluids, and scientists analyzed several alternatives for a drilling strategy. A casing design was accomplished with several failure scenarios that involved cementing the casing and borehole annulus through the salt and retaining drilling fluid in the annulus to determine the nonuniform loading and timing of salt loading on well casing deformation or ovalization. The casing was designed to support the high creep rates of carnallite and tachyhydrite. | Where can we find salt rocks like halite, carnallite and tachyhydrite? | In the Santos basin off Brazil | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Where can we find salt rocks like halite, carnallite and tachyhydrite?
### Response:
In the Santos basin off Brazil <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1522 | In this paper, we describe and analyze the co-management institutional framework at 21 Brazilian Marine Extractive Reserves (MERs) and present the dramas of its implementation from the local manager’s perspective. We categorized the governance instruments of MERs into (i) instruments for land/sea tenure and beneficiaries’ recognition, (ii) territorial use planning, (iii) institutional arenas for discussion and deliberation, as well as (iv) public policies. Although the legal arrangements of these protected areas address fundamental dimensions of governance, we present the challenges of its implementation based on the voice of local managers. The managers are the bridge between the central government and communities, dealing with the implementation of the institutional framework in a reality of multi-level and multi-scale drama: from local to national dilemmas, from organizational to structural ones. We explore these dramas and highlight the institutional dilemmas based on the paradoxes between legalism and social emancipation. | What are the categories of governance instrument of Marine Extractive Reserves (MERs)? | Instruments for land/sea tenure and beneficiaries’ recognition, territorial use planning, institutional arenas for discussion and deliberation as well as public policies. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What are the categories of governance instrument of Marine Extractive Reserves (MERs)?
### Response:
Instruments for land/sea tenure and beneficiaries’ recognition, territorial use planning, institutional arenas for discussion and deliberation as well as public policies. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A516 | In what is being called the first oil and gas sustainable commissioning project, composite abrasives are being used to help conserve precious resources. The core of this sustainable solution includes composite abrasives and an innovative Pipeline Inspection Gauge/Gadget (or pig) system, which were first field tested and then used in Petrobras Refinaria Abreu de Lima, also known as Refinaria do Nordeste (RNEST), in Brazil. This paper focuses on the commissioning of two atmospheric distillation units (ADUs) at RNEST; ADU 11 and ADU 12. During the commissioning process, residual products in pipelines are removed (1) to assure efficient flow though refinery systems and (2) to protect operating equipment. Traditional methods of pipeline cleaning during commissioning typically include cleaning with water, chemical cleaning or steam cleaning. Each of these methods use a high volume of water, produce a high volume of wastewater discharge to be treated, and some have inherent risks to commissioning personnel and/or the environment. Because no water was used during the composite abrasive blasting at RNEST, all water-related steps (e.g. conditioning, drying, special treatment, disposal and storage/disposal) were eliminated. Thus, the number of steps in the cleaning process dropped to four: (1) abrasive blasting pipe internals and (2) applying the appropriate treatment via pig, (3) hydrostatic testing and (4) water treatment/recycling. Using data from the RNEST sustainable commissioning process, this paper will compare common cleaning operations to the new sustasinable commisioning method. Results convey that sustainable commissioning at RNEST used 300,000 liters of reusable water per atmospheric distillation unit versus more than 30 million liters per unit that would have been used with tradtional methods. (This value is estimated based on the RNEST project). In addition to conserving water, sustainable commissioning at RNEST also significantly reduced the time and monetary impact of the commissioning process. The positive environmental and economic results of sustainable commissioning can carry over to similar offshore applications during the commissioning and maintenance of internal piping systems. | What are the traditional methods of cleaning the pipe during commissioning? | methods are water cleaning, chemical cleaning or steam cleaning | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What are the traditional methods of cleaning the pipe during commissioning?
### Response:
methods are water cleaning, chemical cleaning or steam cleaning <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A322 | Invented by Petrobras in 1996, the torpedo anchor has been successfully applied in Floating Production Storage and Offloading (FPSO) in the Gulf of Mexico (Medeiros, 2002). With a torpedo-like hydrodynamic shape, the torpedo anchor obtains the kinetic energy required for penetration by free-falling through the water. It then uses that energy to penetrate into the seabed, thereby completing its installation. This paper discusses the large deformation finite element method and the CEL method, which are used to calculate the torpedo anchor penetration in a cohesive-soil seabed. The characteristics of the soil and the anchor at different moments during the torpedo anchor penetration are analyzed based on simulation results. | Who invented the torpedo anchor? | Petrobras. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Who invented the torpedo anchor?
### Response:
Petrobras. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A707 | Lankhorst Ropes will supply a synthetic high modulus polyethylene (HMPE) mooring rope, the Gama 98 rope construction, to Brazilian oil and gas producer Petrobras, which is developed by the company specifically for deepwater mooring and used on a number of major deepwater projects in the Gulf of Mexico (GoM). This will be the first time the 630-metric-ton minimum breaking load (MBL) rope with Dyneema, comprising 12 sub-ropes of SK78 yarn, has been used for mobile offshore drilling units (MODU) mooring. HMPE is a stiffer yarn than polyester and so its elasticity is significantly less, making it more riser friendly. Although HMPE's creep performance prevents its use for permanent deepwater mooring, it is believed that a polyester/HMPE hybrid mooring system offers the best permanent mooring solution beyond 6,500 ft. The principle benefit of hybrid PE/HMPE ropes is the ability for the mooring system designer to engineer the mooring line's stiffness and use the lengths of polyester and HMPE segments to provide the stiffness needed to handle peak loads during station-keeping. | Where will HPME be used? | In projects developed in the Gulf of Mexico. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Where will HPME be used?
### Response:
In projects developed in the Gulf of Mexico. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A439 | Length–weight relationships (LWR) were determined for seven commercially important species of catfishes (Siluriformes, Ariidae) from the Amazon Coastal Zone (ACZ), Brazil. The analyses included 3628 specimens sampled in three trawling expeditions: dry season of 1996 (111 hauls), rainy season of 1997 (120 hauls), and dry season of 1997 (120 hauls). Bottom-trawl nets were utilized for sampling. Length-weight estimates for Amphiarius phrygiatus, Amphiarius rugispinis, Aspistor quadriscutis, Notarius grandicassis, Sciades couma, Sciades parkeri and Sciades proops. | Where is the Amazon Coastal Zone located? | Brazil | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Where is the Amazon Coastal Zone located?
### Response:
Brazil <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1395 | Lipid biomarkers [fatty acids (FAs), sterols and alcohols] and carbon stable isotopes (δ¹³C values) in surface sediments from 9 cross shelf transects (25–3000 m water depth) from the Campos Basin, SE Brazilian continental margin were analyzed. The aim was to investigate the link between the prevailing regional specific oceanographic conditions (upwelling events, intrusion of cold and nutrient-rich water, low river input) and the nature and distribution of organic matter (OM) in the basin. A general predominance of OM from autochthonous processes, but with a relevant spatial gradient in the quality and quantity of the sedimentary OM, was observed. On the shelf (<150 m), concentrations of lipids were usually low, except in areas influenced by upwelling, but the presence of labile compounds suggested the occurrence of fresh OM in the sediment. The export of continental OM was observed only in shelf sediments near the Paraíba do Sul River. The upper and middle slope (400–1300 m) exhibited the highest concentrations of total organic carbon (TOC) and lipids, but lipid biomarkers suggested the presence of OM with a high degree of bacterial degradation. This may result from the export of material from shallow areas, possibly due to the action of eddies and meandering of the Brazil Current and bottom currents in the region. On the lower slope (1900–3000 m), only the more recalcitrant compounds were above detection limit. The presence of labile lipids in high amount in the shelf and slope suggests the presence of OM with a high potential for supplying the food requirements of heterotrophic organisms in the sediment, which may in turn have a major influence on the ecology of benthic communities. | What was the purpose of the Campos Basin analysis? | Investigate the link between the prevailing regional specific oceanographic conditions (upwelling events, intrusion of cold and nutrient-rich water, low river input) and the nature and distribution of organic matter (OM) in the basin. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What was the purpose of the Campos Basin analysis?
### Response:
Investigate the link between the prevailing regional specific oceanographic conditions (upwelling events, intrusion of cold and nutrient-rich water, low river input) and the nature and distribution of organic matter (OM) in the basin. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1298 | Mangroves are productive ecosystems of tropical coastal landscapes, constituting habitat for many commercial fisheries, as the crab Ucides cordatus. In Brazil this crab holds a major socio-economic importance for artisanal fishery, but with obvious decline on their productivity. In this study we determined and mapped the more suitable mangrove areas for the conservation and fishery of this crab in the São Francisco River Estuary (Northeastern Brazil). We applied a Multi-Criteria Evaluation (MCE) in a GIS environment. Ten criteria in total were used, including crab biotic parameters, land use/cover and social factors. Maps of each criterion were produced by GIS techniques with CBERS and SPOT images and by field data. Mangroves more suitable for the conservation of U. cordatus (9.4 km2) are near to the river mouth, due to high density and frequency of non-commercial size crabs (NCSC), low density of commercial size crabs (CSC), small crabs and low degree of use for fishery. On the other hand, the mangroves for the crab fishery occurred with a similar area (10.2 km2) located farther away from the river mouth, with a high density and frequency of CSC, low density of NCSC, big crabs, medium-high degree of use for fishery and near to the villages. These information and thematic maps can aid government agencies in delineating extractive and fishery exclusion areas, thus contributing to the management plan for this species. | What is the main use of mangrove mapped areas to government? | These information and thematic maps can aid government agencies in delineating extractive and fishery exclusion areas, thus contributing to the management plan for this species. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the main use of mangrove mapped areas to government?
### Response:
These information and thematic maps can aid government agencies in delineating extractive and fishery exclusion areas, thus contributing to the management plan for this species. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1488 | Many estuaries present natural harbor conditions with relatively calm and shallow waters that provide a connection between the ocean and continental waterways. The increase in the demand for goods by the constant growing of the world population has forced estuaries to be altered by human activities, such as dredging, in order to maintain a safe navigation system. The development of sophisticated morphological and hydrodynamic models opened a new perspective of assisting dredging operations inside different estuaries. Thus, the aim of this study is to apply a hydromorphodynamic model to simulate the bed evolution of the Patos Lagoon estuary, southern Brazil. The results of the simulation were applied in a dredge operation model to simulate dredging inside the waterway of the Rio Grande harbor, located inside the Patos Lagoon estuary. The salinity and current velocities inside the estuary were well represented by the model simulations. An annual mean discharge of 3 407 ms3 s?1 was calculated for the lagoon for the year 2004. The morphodynamic model successfully represented the silted and eroded scenarios for the estuarine channel. The dredge operation model results affirm that dredging of the channel causes significant variations in estuarine physical parameters such as salinity, current velocity and suspended sediment concentration. The bed evolution results indicate that a fast siltation of the channel occurs right after dredging stops, stabilizing the variations after a 60-day period. | What happens when there is and when there is no dredging in a channel? | Dredging causes variations in physical parameters such as salinity, current speed and concentration of suspended sediments. When the dredging ceases, the channel silts up quickly, and after a period of 60 days, the variations stabilize. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What happens when there is and when there is no dredging in a channel?
### Response:
Dredging causes variations in physical parameters such as salinity, current speed and concentration of suspended sediments. When the dredging ceases, the channel silts up quickly, and after a period of 60 days, the variations stabilize. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1765 | Mapping of natural gas hydrate systems has been performed successfully in the past using the controlled source electromagnetic (CSEM) method. This method relies on differentiating resistive highly saturated free gas or hydrate bearing host sediment from a less resistive low-saturated gas or brine-bearing host sediments. Knowledge of the lateral extent and resistivity variations (and hence the saturation variations) within sediments that host hydrates is crucial to be able to accurately quantify the presence of saturated gas hydrates. A 3D CSEM survey (PUCRS14) was acquired in 2014 in the Pelotas Basin offshore Brazil, with hydrate resistivity mapping as the main objective. The survey was acquired within the context of the CONEGAS research project which investigated the origin and distribution of gas hydrate deposits in the Pelotas Basin. We inverted the acquired data using a proprietary 3D CSEM anisotropic inversion algorithm. Inversion was purely CSEM data-driven, and we did not include any a-priori information in the process. Prior to CSEM, interpretation of near-surface geophysical data including 2D seismic, sub-bottom profiler and multibeam bathymetry data indicated possible presence of gas hydrates within features identified such as faults, chimneys and seeps leading to pockmarks, along the bottom simulating reflector (BSR) and within the gas hydrate stability zone. Upon integration of the same with CSEM derived resistivity volume, the interpretation revealed excellent spatial correlation with many of these features. The interpretation further revealed new features with possible hydrate presence, which were previously overlooked due to a lack of a clear seismic and/or multibeam backscatter signature. Also, features which were previously mapped as gas hydrate bearing had to be reinterpreted as residual or low saturated gas/hydrate features, due to lack of significant resistivity response associated with them. We further used the inverted resistivity volume to derive saturation volume of the subsurface using Archie's equation. | How can we successfully map a natural gas hydrate systems? | Using a controlled source electromagnetic method. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
How can we successfully map a natural gas hydrate systems?
### Response:
Using a controlled source electromagnetic method. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A449 | Marginal Oilfields are refered to as those oilfields that are hardly developed efficiently with current technical and ecomonical conditions, characterized as high costs of development and low profit margins. However, under certain economical and technical circumstances, marginal oilfields may be transferred to be conventional ones. Since Petrobras developed the first ever offshore deep reservoir (Lula) by scale in 2006, Brazil has been conducting a progressive campaign targeting hydrocarbons buried under deep water, which contributes to discovery of Lula, Carioca, Jupiter, Buzios, Libra and other giant presalt reservoirs in Santos Basin. CNPC signed a cooperation contract with Petrobras in 2013, taking 10% of the total shares. How to efficiently develop the oilfield has been a challenging issue. Technologies of smart water injection in Shengli Oilfield have been studied, while the field development and environment (deep water) of Libra Oilfield have been analyzed, in order that the smart water injection technologies may be modified to develop the marginal oilfield more efficiently. Different from conventional zonal water injection technologies, the remote wireless control water injection technologies take advantages of packers that are connected with each other via preset cables, which achieves downhole testing and water injection simultaneously. Being run via tubing, the water injection string locates a nozzle for each reservoir that is isolated by a packer. All nozzles are connected with packers via the preset cables that work as power lines for the whole string, so that downhole data such as pressures, flows and temperatures are all transferred to the processing computer on the surface. The computer program is used to convert pressure and formation signals into curves that are transferred to Company via WIFI or mobile 2G/3G/4G webs, in order that technicians there may understand and learn about downhole pressures, temperatures, flows and nozzle conditions in real time. They are able to open and close the nozzles totally or partially by giving orders that are transferred as signals via cables. In order to cope with offshore environment of Libra Oilfield in Santos Basin, pre-set cable packers have been modified accordingly, so that highly deviated wells may be developed with the smart water injection technologies. A field trial deployed in BM-C-33 Block Libra Oilfield shows that the modified smart water injection technologies are feasible for Libra Oilfield, as a novel solution to inject water in highly-deviated and horizontal wells in offshore oilfields. | What is the role of the computer program in the research? | It is used to convert the pressure and formation signals into curves, so that technicians there may analyze and learn about. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the role of the computer program in the research?
### Response:
It is used to convert the pressure and formation signals into curves, so that technicians there may analyze and learn about. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1416 | Marine mining is the ocean’s new exploration frontier, and polymetallic crusts (PMCs) and ferromanganese nodules are considered a strategic resource for the future. Acoustic geophysical methods are a valuable tool for oceanic research and have been employed for several decades in the exploration of marine resources and environmental evaluations. The main objective of this work was to investigate the correlation between the chemical composition of PMCs from three different areas along the Brazilian continental margin and their physico-acoustic attributes (P-wave velocity, density and acoustic impedance). The results show that the geoacoustic properties of PMCs are correlated to their chemical composition. Measurements showed positive and negative trends between acoustic impedance and studied elements (Fe, Mn, Co, Cu, Zn, W and Ni) according to the direction of measurement, indicting high anisotropy levels. Our study sheds initial light on the correlation between acoustic properties and metal content of PMCs. The study facilitates assessments of the acoustic responses of PMCs allowing more efficient prospection and exploitation compared to ship-board geophysical techniques that are too qualitative to identify PMCs. The results can contribute to determining the best procedures and techniques for more efficient future exploration of this resource. | Which kind of resource of the crusts is marine mining interested in? | The large variety of metals that can be found in it | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Which kind of resource of the crusts is marine mining interested in?
### Response:
The large variety of metals that can be found in it <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A150 | Martin Vaz Archipelago is located at the parallel 20°S, 1200 km away from the Brazilian coastline and is composed of Plio-Pleistocenic alkaline rocks that represent the last volcanic event of the Vitória-Trindade Ridge. The Archipelago is divided into three main units: Pico das Gaivotas Unit (i) is made up of nosean-phonolite and phono-tephrite domes and tephri-phonolite dykes with clinopyroxene, nosean and potassic feldspar phenocrysts, and scarce kaersutite anhedral phenocrysts; the Bandeira Unit (ii), in turn, comprises melanephelinitic and basanitic lava flows with olivine and clinopyroxene (diopside) phenocrysts; and lastly, the Basal Unit (iii) is composed of pyroclastic deposits with tuffs, lapilli-tuffs and lapillite. The clinopyroxene phenocrysts from Pico das Gaivotas and Bandeira Units have anhedral green cores with sieved and poikilitic textures and show reaction rims composed of opaque minerals, indicating disequilibrium and compositional changes in the liquid. This study provides mineral chemistry data indicating that clinopyroxene rims are more primitive (Mg# 57.46–84.12) and enriched in Al–Ti–Fe3+-Ca compared to the Fe-rich green-cores, probably related with a more primitive Ca-rich magma input in the magmatic chamber after the green-core crystallization from a different liquid. Olivine crystals from Bandeira Unit show resorption features and no compositional affinity with the analyzed liquid, indicating that these crystals have a xenocrystic origin from mantle peridotitic source. Clinopyroxene geothermobarometry data suggest different pressure and temperature conditions for cores and rims during crystallization, reflecting a polybaric evolutionary history. Pico das Gaivotas Unit clinopyroxene phenocrysts suggest a particularly higher-pressure environment, and a complex evolutionary history. | What type of rocks is the Martin Vaz Archipelago composed of? | Plio-Pleistocenic alkaline rocks | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What type of rocks is the Martin Vaz Archipelago composed of?
### Response:
Plio-Pleistocenic alkaline rocks <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1835 | Mega oil and gas reservoirs have been discovered in deep and ultra-deep offshore Brazil. These Pre-Salt discoveries are remotely located at water depths ranging from 2200m (~7,200 ft) to 2600 m (~8,500 ft). Offshore Brazil has unique metocean conditions with long swell periods which present challenges on floating platforms such as Spars and Semis. In addition, the remoteness of location and the associated high cost of vessel mobilization add further pressure on economics and risk. Quayside integration is thus a desired feature of the hull concept in order to eliminate offshore mating and the associated risk to cost and schedule. To explore these pre-salt complicated ultra-deepwater reservoirs usually require large drilling rig and drilling variable payload which result in very large topsides in both size and weight. Spars and TLPs are the only two proven dry tree hull forms in deep and ultra-deep waters in the GOM. However the TLP becomes cost prohibitive if the water depth is beyond 1,524 m (5,000 ft). For large payload systems requiring a large drilling rig, a suitable Spar size creates a challenge for transportation and installation. The semi-submersible hull form is known to offer advantages over Spars such as larger deck space and quayside integration which are essential to reducing offshore commissioning time and risk as well as cost and schedule. Maturation of the dry tree semi-submersible solution in GoM ultra-deepwater (2,400m) had been undertaken by RPSEA and dry tree Paired Column Semisubmersible (PC Semi) platform, developed by Houston Offshore Engineering, was selected by the RPSEA committee in 2009. Extensive wind tunnel tests and wave basin model tests including 1,000-year central GoM hurricanes were successfully completed in 2010. PC Semi hull configuration, TTR stroke, the analytical results and simulation tools had been fully validated. This paper presents validation analysis results of a dry tree PC semi developed with conventional RAM style tensioners, in 2,400m ultra-deepwater of Offshore Brazil Pre-Salt carrying same topsides payloads as RPSEA. The validation analysis was performed by the correlated analysis tools and established analysis procedures. The design efficiencies including payload, steel weight and production efficiencies of PC Semis for BPS and central GoM are addressed and discussed. Highly efficient PC Semi for BPS has been developed, validated and became "market ready". | What is the best way to explore the Mega oil and gas reservoirs in deep and ultra-deep waters off the coast of Brazil? | The semi-dry PC developed with conventional tensioners of the RAM type, in 2,400m of ultra-deep waters of the Brazilian Offshore Pre-Salt was developed, validated as a good exploration mode. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the best way to explore the Mega oil and gas reservoirs in deep and ultra-deep waters off the coast of Brazil?
### Response:
The semi-dry PC developed with conventional tensioners of the RAM type, in 2,400m of ultra-deep waters of the Brazilian Offshore Pre-Salt was developed, validated as a good exploration mode. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A413 | Most of Brazilian oil and gas reserves are located in offshore deep waters. In this scenario, high well productivity is essential. Artificial lift will certainly play an important role in the exploitation of those deep water fields. This paper describes the most important artificial lift methods, their main characteristics and application niches. It also shows what Petrobras is currently doing in order to make them available for subsea use. The following methods are analyzed: gas lift; electrical submersible pump; hydraulic jet pump; progressing cavity pump; multiphase pump; subsea separation system. | What are some of the artificial lift methods? | The methods are gas lift, electrical submersible pump, hydraulic jet pump, progressing cavity pump, multiphase pump, subsea separation system. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What are some of the artificial lift methods?
### Response:
The methods are gas lift, electrical submersible pump, hydraulic jet pump, progressing cavity pump, multiphase pump, subsea separation system. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A897 | Most of Brazilian oil and gas reserves are located in offshore deep waters. In this scenario, high well productivity is essential. Artificial lift will certainly play an important role in the exploitation of those deep water fields. This paper describes the most important artificial lift methods, their main characteristics and application niches. It also shows what Petrobras is currently doing in order to make them available for subsea use. The following methods are analyzed: gas lift; electrical submersible pump; hydraulic jet pump; progressing cavity pump; multiphase pump; subsea separation system. | What is Petrobras' interest in artificial lifiting? | Petrobras is studying manners of offshore gas exploration. Artificial lifting is one of them. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is Petrobras' interest in artificial lifiting?
### Response:
Petrobras is studying manners of offshore gas exploration. Artificial lifting is one of them. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1044 | Norsk Hydro has congratulated Baker Oil Tools for its installation of the InForce Intelligent Well System in the Snorre field in the North Sea, which is the first ever installation of the system in the area. The installation will help Hydro reduce rig cost, as well as facilitate production from the P-30 well. The installation allows each zone of the well to be accessed or closed remotely in less than 5 min. Baker has previously installed other, equally successful hydraulic intelligent well systems in the Middle East and Far East. Meanwhjile, Baker's InCharge Intelligent Well System has been licensed by Petrobras for its ultra-deepwater exploration of the Roncador field. | Where has Baker installed successful smart hydraulic well systems? | In the North Sea, Middle East and Far East. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Where has Baker installed successful smart hydraulic well systems?
### Response:
In the North Sea, Middle East and Far East. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A482 | Norsk Hydro has congratulated Baker Oil Tools for its installation of the InForce Intelligent Well System in the Snorre field in the North Sea, which is the first ever installation of the system in the area. The installation will help Hydro reduce rig cost, as well as facilitate production from the P-30 well. The installation allows each zone of the well to be accessed or closed remotely in less than 5 min. Baker has previously installed other, equally successful hydraulic intelligent well systems in the Middle East and Far East. Meanwhjile, Baker's InCharge Intelligent Well System has been licensed by Petrobras for its ultra-deepwater exploration of the Roncador field. | What are the benefits of the InForce Intelligent Well System? | It reduces the rig costs and allows each zone to be accessed or closed remotly in less than 5 minutes. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What are the benefits of the InForce Intelligent Well System?
### Response:
It reduces the rig costs and allows each zone to be accessed or closed remotly in less than 5 minutes. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1453 | Nowadays gas-lift is still a very expressive artificial lift method, for instance considering the whole Brazilian oil production profiles, gas lifted wells are responsible for 30% of monthly production. Due this huge importance, the injection efficiency should be ensured to avoid lid gas losses and maximize the production. Then, this study had as objective to develop a Gas Lift Optimization workflow and define the optimum lift rates to increase the reservoir recovery and improve gas usability due to platform constraints of a Brazilian deep-water field. That workflow comprises a reservoir and flow assurance simulators, achieving more accurate responses compared to regular workflows. Taking advantages of the proposed method, multidisciplinary teams could work together which increases the representativeness of such studies providing important outcomes for decision makers. At this study, due to a gas-lift optimization was observed an increase of 0.5% at cumulative production with a huge gas-lift reduction of around 40%, resulting in a better financial balance of the project, saving a considerable amount of lift-gas. The methodology adopted to optimize the injected gas lift rate and consequently increase/maintain cumulative oil production proved adequate for application in oil fields that are highly dependent on artificial lift methods. Therefore, exploration and production projects can be financial healthier. | Nowadays considering the profile of oil production in Brazil, how much do the wells that use the artificial elevation technique contribute to national oil production? | Wells raised with gas are responsible for 30% of monthly production. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Nowadays considering the profile of oil production in Brazil, how much do the wells that use the artificial elevation technique contribute to national oil production?
### Response:
Wells raised with gas are responsible for 30% of monthly production. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1168 | On July 16, 2000, a crude oil spill occurred at the PETROBRAS refinery Refinaria Presidente Getúlio Vargas-REPAR, located in Araucária, PR, Brazil A significant quantity of oil was retained within an area known as Ponto 0, between the spill site and Rio Barigüi, contaminating the banks of a small stream (Arroio Saldanha), the soil adjacent to the stream, and the soil of four small wetlands, over a distance of 2 km. This paper presents an overview of the remediation program for Ponto 0, and draws preliminary conclusions regarding the efficacy of different remediation technologies. The major remediation technologies are: 1) injection and recovery trenches for free-product recovery in the sector adjacent to the spill site; 2) in situ bioremediation along the floodplain of Arroio Saldanha; and 3) a treatment wetland near the discharge of Arroio Saldanha into Rio Barigüi. The trenches appear to have removed most of the free product from the sector adjacent to the spill site. There is preliminary evidence, based on soil monitoring data, for the efficacy of in situ bioremediation, but further data will be required before a firm conclusion can be drawn. The treatment wetland was successful in restoring wetland vegetation (an essential component of this technology), and appears to be capable of removing hydrocarbons from groundwater. Data of the groundwater monitoring program indicates a general decline in TPH concentrations, over the October 2000, August 2001 and April 2002 sampling campaigns. BTEX concentrations are generally below the method detection limit. | What are the results of the methods in the recovery of the oil spill near the Barigui River? | The trenches seem to have removed most of the free product from the sector adjacent to the spill site, and the swamp treatment has managed to restore its vegetation. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What are the results of the methods in the recovery of the oil spill near the Barigui River?
### Response:
The trenches seem to have removed most of the free product from the sector adjacent to the spill site, and the swamp treatment has managed to restore its vegetation. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1569 | One late Quaternary sediment core from the continental slope of the northern sector of Pelotas Basin (southern Brazilian continental margin, 2091 m water depth) was analyzed in order to evaluate the influence of the organic matter influx in the benthic foraminiferal assemblage composition on a regional scale. This study investigated the relationship between epifaunal species (Epistominella exigua and Alabaminella weddellensis) and infaunal species (Uvigerina peregrina and Angulogerina angulosa) integrated in a relative abundance based index, the “Organic Input Index” (OrgIn). The correlation of these species with abiotic data is also discussed, including mud content, total organic carbon (TOC) and carbon stable isotope (?13C) in Uvigerina peregrina. The age model based on one radiocarbon dating of planktonic foraminifera and oxygen isotope composition of benthic foraminifera (Uvigerina) revealed the record spans the last 112,500 yr, covering the Marine Isotope Stages (MIS) 5 to 3. The dominance of infaunal species, mainly Globocassidulina subglobosa, boliviniids and buliminiids throughout the entire core is interpreted as an indicator of an increase of organic matter supply and dominance of the eutrophic conditions in this study area. The variations found in the proportion of the epifaunal and infaunal species indicate distinctive inputs of organic matter (phytodetritus input versus bacterial activity, respectively). An increasing trend in the importance of epifaunal species from the base of the core to uppermost samples (MIS 5 to MIS 3) was also observed, which is assumed to be evidence of the higher productivity of the surface water masses in this sector of the South Atlantic during the glacial periods. | Which infanit and epifaunal species were embarrassed in the study? | Epifaunal species: epistominella requires and alabaminella weddellensis; and Infaunal Species: pilgrim uvigerine and angulogerine. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Which infanit and epifaunal species were embarrassed in the study?
### Response:
Epifaunal species: epistominella requires and alabaminella weddellensis; and Infaunal Species: pilgrim uvigerine and angulogerine. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A436 | Parque das Conchas is an ultra-deepwater heavy oil development located in the northern Campos basin offshore Brazil. The project is a joint venture between Shell, Petrobras, and ONGC. The first phase of the project is the development of 3 independent subsea fields tied back to the centrally located turret moored floating, production, storage and offloading (FPSO) host facility entitled the FPSO Espirito Santo. The phase 1 Abalone, Ostra, and Argonauta B west fields are small to medium in size, with low-pressured reservoirs, and range in oil gravities from 17° to 42° API. A fourth 16° API gravity heavy oil field requiring water flood, Argonauta O north, will be tied back as part of phase 2 and is planned to be ready for production in 2013. The phase 1 subsea infrastructure consists of 10 producing wells and 1 gas injection well connected via 140 kilometers of pipelines and flowlines ranging in size from 6? to 12?, 15 flowline sleds, 2 production manifolds, 2 artificial lift manifolds housing a total of 6 vertical subsea separation caissons with 1500 hp ESP's, 25 jumpers, all of which are serviced by 30 kilometers of high voltage multi-circuit electro/hydraulic umbilicals and 20 kilometers of static electro-hydraulic umbilicals. The FPSO Espirito Santo is a converted 1975 VLCC moored in 1,780 meters of water and equipped to process 100,000 bopd, 50 MMscfpd, with 1.4 million barrels of oil storage capacity. The Parque das Conchas development is the result of a 9-year effort to understand the complex geology, identify sufficient reserves to support a development, identify an economic development concept, and to design, mature and apply the significant new technologies required to safely execute the project during an extremely volatile market period. This paper provides an overview of the development and execution of the project, highlights new technologies that have been developed and implemented and introduces the key challenges, achievements, and learning's in various parts of the project and the tight integration between all disciplines required to successfully deliver the Parque das Conchas project. Additional details can be found in the dedicated support papers have been generated and listed in the Reference section of this paper. | Which companies are participating in the project at Parque das Conchas? | The project is a joint venture between Shell, Petrobras, and ONGC. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Which companies are participating in the project at Parque das Conchas?
### Response:
The project is a joint venture between Shell, Petrobras, and ONGC. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1589 | Passive margins underlain by a salt detachment are typically interpreted as kinematically linked zones of updip extension and downdip contraction separated by a zone of translation above a smoothly dipping base of salt. However, salt flow is affected by the base-of-salt geometry across which it flows, and early-stage gravity gliding induced by basin tilt may be complicated by the presence of salt-thickness changes caused by the pre-existing base-salt relief. We investigate these effects using physical models. Dip-parallel steps generate strike-slip fault zones separating domains of differential downslope translation and structural styles, provided the overburden is thin enough. If the overburden is thicker, it resists breakup, but a change in the structural trend occurs across the step. Steps with mild obliquity to the dip direction produce transtensional and transpressional faults in the cover separating structural domains. Deformation complexity in the overburden increases where base-salt steps strike at a high angle to salt flow, and it is especially dependent on the ratio between the thick (T) and thin (t) salt across the step at the base of salt. Where the salt-thickness ratio (T/t) is high, basal drag generates major flux mismatches, resulting in a contractional thickening of the salt and associated overburden shortening in thin salt above a base-salt high block. Shortening is transient and superseded by extension as the salt thickening allows the flow velocity to increase. When transitioning off a base-salt high block into a low block, the greater flux within the thick salt results in a monocline with extensional and contractional hinges. Structures are further deformed as they translate through these hinge zones. Our physical models demonstrate that extensional diapirs and compressional fold belts can be initiated anywhere on a slope as the salt accelerates and decelerates across base-salt relief. A fold belt from the Campos Basin, offshore Brazil, is used to illustrate these processes. | Why should the overburden be thin enough during dip-parallel steps? | Because if the overburden is thicker, it resists breakage. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Why should the overburden be thin enough during dip-parallel steps?
### Response:
Because if the overburden is thicker, it resists breakage. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1590 | Passive margins underlain by a salt detachment are typically interpreted as kinematically linked zones of updip extension and downdip contraction separated by a zone of translation above a smoothly dipping base of salt. However, salt flow is affected by the base-of-salt geometry across which it flows, and early-stage gravity gliding induced by basin tilt may be complicated by the presence of salt-thickness changes caused by the pre-existing base-salt relief. We investigate these effects using physical models. Dip-parallel steps generate strike-slip fault zones separating domains of differential downslope translation and structural styles, provided the overburden is thin enough. If the overburden is thicker, it resists breakup, but a change in the structural trend occurs across the step. Steps with mild obliquity to the dip direction produce transtensional and transpressional faults in the cover separating structural domains. Deformation complexity in the overburden increases where base-salt steps strike at a high angle to salt flow, and it is especially dependent on the ratio between the thick (T) and thin (t) salt across the step at the base of salt. Where the salt-thickness ratio (T/t) is high, basal drag generates major flux mismatches, resulting in a contractional thickening of the salt and associated overburden shortening in thin salt above a base-salt high block. Shortening is transient and superseded by extension as the salt thickening allows the flow velocity to increase. When transitioning off a base-salt high block into a low block, the greater flux within the thick salt results in a monocline with extensional and contractional hinges. Structures are further deformed as they translate through these hinge zones. Our physical models demonstrate that extensional diapirs and compressional fold belts can be initiated anywhere on a slope as the salt accelerates and decelerates across base-salt relief. A fold belt from the Campos Basin, offshore Brazil, is used to illustrate these processes. | What happens where the salt-thickness ratio is high and what does it result in? | Basal drag generates major flux mismatches, which results in contractional thickening of the salt and associated overburden shortening. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What happens where the salt-thickness ratio is high and what does it result in?
### Response:
Basal drag generates major flux mismatches, which results in contractional thickening of the salt and associated overburden shortening. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A296 | Petrobras and the UK's BG Group are studying the possibility of installing floating gas-liquefaction plants at the large offshore oil and gas discoveries in the Campos basin's pre-salt areas. The proposed 14 million cu m/day LNG plant would be moored 300 km offshore and would collect gas from various fields in the area, including the giant Tupi discovery. LNG would be delivered to domestic terminals during the country's dry season when, gas-fired power generation supplements hydropower, and exported at other times. | What would be the destination of the LNG of the plant proposed by Petrobras and the UK's BG Group? | Domestic terminals. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What would be the destination of the LNG of the plant proposed by Petrobras and the UK's BG Group?
### Response:
Domestic terminals. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1117 | Petrobras announced a "giant" discovery in the northern part of Campos Basin, of at least an estimated recoverable 0.6 billion bbl of heavy oil. The reservoir, about 80 km offshore, was initially discovered in January 2001. The country's last major find, the 3 billion bbl, ultra-deep-water Roncador field, was made by Petrobras in 1996. | How far offshore is the reservoir found by Petrobras on Campos basin containing an estimate of 0.6 billion bbl of heavy oil? | About 80 km offshore | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
How far offshore is the reservoir found by Petrobras on Campos basin containing an estimate of 0.6 billion bbl of heavy oil?
### Response:
About 80 km offshore <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A466 | Petrobras announced a "giant" discovery in the northern part of Campos Basin, of at least an estimated recoverable 0.6 billion bbl of heavy oil. The reservoir, about 80 km offshore, was initially discovered in January 2001. The country's last major find, the 3 billion bbl, ultra-deep-water Roncador field, was made by Petrobras in 1996. | When was the last discovery made in relation to the Roncador field made by Petrobras? | The discovery was made in 1996. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
When was the last discovery made in relation to the Roncador field made by Petrobras?
### Response:
The discovery was made in 1996. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A663 | Petrobras announced a "giant" discovery in the northern part of Campos Basin, of at least an estimated recoverable 0.6 billion bbl of heavy oil. The reservoir, about 80 km offshore, was initially discovered in January 2001. The country's last major find, the 3 billion bbl, ultra-deep-water Roncador field, was made by Petrobras in 1996. | When was the Roncador field found by Petrobras? | 1996 | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
When was the Roncador field found by Petrobras?
### Response:
1996 <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A279 | Petrobras has awarded Excelerate Energy a 15-yr time charter for which Excelerate will provide an advanced floating storage and regasification unit (FSRU) to be named by Petrobras VT3. Capable of storing 173,400 cu m, the vessel will deliver 20 million cu m/day of natural gas to southeastern Brazil. In addition, from July 2013 until the arrival of the VT3 newbuilding, Petrobras' Guanabara Bay LNG terminal will use Excelerate's Exquisite FSRU with an increased regasification plant, expanding the terminal's delivery capacity from 14 million to 20 million cu m/day. The VT3 newbuilding design is based on Excelerate's existing fleet and Petrobras requirements. Capable of operating as both an FSRU and a fully tradable LNG carrier, the vessel is to enter service in May 2014. | What is the duration of Petrobras' concession to Excelerate Energy? | The duration of the concession is 15 years. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the duration of Petrobras' concession to Excelerate Energy?
### Response:
The duration of the concession is 15 years. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A445 | Petrobras has launched the 38-in., 179-km Cabiunas-Reduc III (Gasduc III) gas pipeline, which is capable of carrying 40 million cu m/day. Gasduc III enhances regional transportation capacity to 40 million from 16 million cu m/day. The line can transport gas produced in the Campos and Espirito Santo basins, as well as gas imported from Bolivia and from the Guanabara Bay LNG Regasification Terminal. Gasduc III also will be able to receive gas coming from the Santos Basin, once the Caraguatatuba-Taubate gas pipeline has been completed in later 2010. Gasduc III interconnects Brazil's main natural gas processing pole, the Cabiúnas Terminal, to natural gas Hub 2, in Duque de Caxias. According to Petrobras, in addition to the Paulinia-Jacutinga gas pipeline, the transportation network that supplies the state of Minas Gerais will be further reinforced in May 2010 when the 267-km Gasbel II line is scheduled to begin operating. With the Paulinia-Jacutinga and Gasbel II gas pipelines, Petrobras will boost its natural gas transportation capacity to Minas Gerais fourfold, rising to 13.2 million from 3.2 million cu m/day. | What is the transport capacity of the Cabiunas-Reduc III's gasoduct in cubic meters? | 40 million cu m/day. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the transport capacity of the Cabiunas-Reduc III's gasoduct in cubic meters?
### Response:
40 million cu m/day. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A425 | Petrobras increased its oil production capacity by 100,000 bpd following the start-up of operations at the Marlim Sul floating production, storage, and offloading vessel (FPSO), at the Marlim Sul field, in the Campos basin. Petrobras has leased the FPSO from the US' Single Buoy Moorings since January 2003. The new platform should start production at 20,000-25,000 bpd and reach full capacity by the end of 2004. Total output in the Campos basin averaged 1.2 million bpd of oil and NGL in the first 4 mo of 2004, equivalent to ~ 80% of the country's production. The FPSO is 110-km offshore Rio de Janeiro state and operates at water depths of 1160 m. Production from Marlim Sul averaged 151,000 bpd in 2003. Another platform, the 180,000-bpd P-51, is also planned for the Marlim Sul field and is due on stream in 2008. | How did Petrobras increase its oil production capacity by 100 thousand bpd? | It followed the start-up of operations at the Marlim Sul floating production, storage, and offloading vessel (FPSO), at the Marlim Sul field, in the Campos basin. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
How did Petrobras increase its oil production capacity by 100 thousand bpd?
### Response:
It followed the start-up of operations at the Marlim Sul floating production, storage, and offloading vessel (FPSO), at the Marlim Sul field, in the Campos basin. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A918 | Petrobras increased its oil production capacity by 100,000 bpd following the start-up of operations at the Marlim Sul floating production, storage, and offloading vessel (FPSO), at the Marlim Sul field, in the Campos basin. Petrobras has leased the FPSO from the US' Single Buoy Moorings since January 2003. The new platform should start production at 20,000-25,000 bpd and reach full capacity by the end of 2004. Total output in the Campos basin averaged 1.2 million bpd of oil and NGL in the first 4 mo of 2004, equivalent to ~ 80% of the country's production. The FPSO is 110-km offshore Rio de Janeiro state and operates at water depths of 1160 m. Production from Marlim Sul averaged 151,000 bpd in 2003. Another platform, the 180,000-bpd P-51, is also planned for the Marlim Sul field and is due on stream in 2008. | Oil production in the Campos basin in the first 4 months of 2004 represents how much of the country's production? | Approximately 80% | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Oil production in the Campos basin in the first 4 months of 2004 represents how much of the country's production?
### Response:
Approximately 80% <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A426 | Petrobras increased its oil production capacity by 100,000 bpd following the start-up of operations at the Marlim Sul floating production, storage, and offloading vessel (FPSO), at the Marlim Sul field, in the Campos basin. Petrobras has leased the FPSO from the US' Single Buoy Moorings since January 2003. The new platform should start production at 20,000-25,000 bpd and reach full capacity by the end of 2004. Total output in the Campos basin averaged 1.2 million bpd of oil and NGL in the first 4 mo of 2004, equivalent to ~ 80% of the country's production. The FPSO is 110-km offshore Rio de Janeiro state and operates at water depths of 1160 m. Production from Marlim Sul averaged 151,000 bpd in 2003. Another platform, the 180,000-bpd P-51, is also planned for the Marlim Sul field and is due on stream in 2008. | What is the approximate contribution of the total production of the Campos basin in 2004 in Brazil? | Equivalent to 80% of the country's production. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the approximate contribution of the total production of the Campos basin in 2004 in Brazil?
### Response:
Equivalent to 80% of the country's production. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A1394 | Petrobras is assessing the potential of the Santos basin presalt reservoirs offshore Brazil. Three integrated ultrafast-track projects were planned to start production of the giant presalt reservoirs in an area known as Tupi. The objective of the three projects is to obtain relevant reservoir and production data to support the design phase of the remaining production units of the full-field development. The main technical challenges addressed include drilling complex wells, use of intelligent completions, qualifying ultradeepwater risers, establishing flow assurance through long subsea flowlines, and CO2 capture and sequestration. | Where is Petrobras evaluating a potential pre-salt reservoir? | Santos basin presalt reservoirs offshore Brazil | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Where is Petrobras evaluating a potential pre-salt reservoir?
### Response:
Santos basin presalt reservoirs offshore Brazil <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A598 | Petrobras will invest at least $3.5 billion in the northeastern state of Bahia through 2010 to expand the local gas networks, boost oil and gas output, and improve refining capabilities. Among the projects, Petrobras plans to invest over $1.2 billion to develop gas produciton at the offshore Manati field in the Camamu-Almada basin. Production should start by January 2006, with output reaching about 4.5 million cu m/day of gas, increasing the state's gas production to 11 million cu m/day of gas. | What is the productive capacity of the Manati field? | 4.5 million m³ | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the productive capacity of the Manati field?
### Response:
4.5 million m³ <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A737 | Petrobras will invest at least $3.5 billion in the northeastern state of Bahia through 2010 to expand the local gas networks, boost oil and gas output, and improve refining capabilities. Among the projects, Petrobras plans to invest over $1.2 billion to develop gas produciton at the offshore Manati field in the Camamu-Almada basin. Production should start by January 2006, with output reaching about 4.5 million cu m/day of gas, increasing the state's gas production to 11 million cu m/day of gas. | Why does Petrobras want to invest in the northeastern Bahia? | In order to expand the local gas networks, boost oil and gas output, and improve refining capabilities. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
Why does Petrobras want to invest in the northeastern Bahia?
### Response:
In order to expand the local gas networks, boost oil and gas output, and improve refining capabilities. <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A852 | Petrobras will invest at least $3.5 billion in the northeastern state of Bahia through 2010 to expand the local gas networks, boost oil and gas output, and improve refining capabilities. Among the projects, Petrobras plans to invest over $1.2 billion to develop gas produciton at the offshore Manati field in the Camamu-Almada basin. Production should start by January 2006, with output reaching about 4.5 million cu m/day of gas, increasing the state's gas production to 11 million cu m/day of gas. | What is the gas production in the state of Bahia in 2010? | The state's gas production is 11 million m3 / day of gas in 2010 | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
What is the gas production in the state of Bahia in 2010?
### Response:
The state's gas production is 11 million m3 / day of gas in 2010 <|end_of_text|> |
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets. | A874 | Petrobras will invest at least $3.5 billion in the northeastern state of Bahia through 2010 to expand the local gas networks, boost oil and gas output, and improve refining capabilities. Among the projects, Petrobras plans to invest over $1.2 billion to develop gas produciton at the offshore Manati field in the Camamu-Almada basin. Production should start by January 2006, with output reaching about 4.5 million cu m/day of gas, increasing the state's gas production to 11 million cu m/day of gas. | How much more gas was expected to be produced by day in Bahia with Petrobras' investments in 2010? | The state's gas production will be increased to 11 million cu m/day of gas. | ### Instruction:
You are an assistant specialized in answering questions with clarity and accuracy, using the information from the provided question-and-answer datasets.
### Input:
How much more gas was expected to be produced by day in Bahia with Petrobras' investments in 2010?
### Response:
The state's gas production will be increased to 11 million cu m/day of gas. <|end_of_text|> |
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