As the hunger for data grows, long stepouts become more common, and fiber communication becomes standard, the use of fiber in subsea oil and gas fields is set to increase. The paper provides a fast-track approach to perform screening assessment of multiple subsea concepts. Technologies are being developed that have the potential to support marine mining in all stages from prospection to decommissioning. When two engineers lost their jobs during the industry downturn, they used the misfortune as an opportunity to develop an innovative concept that aims to make it a lot easier to move subsea gas long distances. Currently, the state of the art for subsea well control is based on hydraulic technology.
The operator piloted a new well-completion design combining inflow-control valves (ICVs) in the shallow reservoir and inflow-control devices (ICDs) in the deeper reservoir, both deployed in a water-injector well for the first time in the company’s experience. In this paper, the authors describe a project to design, field trial, and qualify an alternative solution for real-time monitoring of the oil rim in carbonate reservoirs that overcomes these disadvantages. The authors detail the development of a technique based on surface-to-borehole controlled-source electromagnetics (CSEM), which exploits the large contrast in resistivity between injected water and oil to derive 3D resistivity distributions, proportional to saturations, in the reservoir. This industry is one often considered reactive and overly tradition-bound. These new technologies, however—and, more importantly, the drive of these researchers to harness their capabilities—prove that petroleum engineers remain at the forefront of innovation and discovery.
Petrobras and Shell have brought online the Lula field’s seventh FPSO as the firms continue to ramp up production from the pre-salt Santos Basin. This paper presents the development of Sapinhoá field, covering the fast-track transition and decision-making process, from appraisal to conceptual and basic engineering of the Sapinhoá pilot project and on to its subsequent execution, highlighting the challenges, lessons learned, and results.
Petrobras and Shell have brought online the Lula field’s seventh FPSO as the firms continue to ramp up production from the pre-salt Santos Basin. The paper provides a fast-track approach to perform screening assessment of multiple subsea concepts. Since the first intelligent completion was installed 20 years ago, the systems have become increasingly complex in order to reach productivity and optimization goals, allowing real-time independent monitoring and management of each zone in the well. This paper describes an extended-well-test campaign using intelligent completions in a presalt reservoir. To understand reservoir behavior during production better, several options were analyzed for the first extended well test.
Petrobras and Shell have brought online the Lula field’s seventh FPSO as the firms continue to ramp up production from the pre-salt Santos Basin. The national oil company’s aim to lift oil and gas production and reserves over the next few years will rely on growth from big international projects, including those in Nigeria, Guyana, and the US.
Africa (Sub-Sahara) United Hydrocarbon International finished drilling the Belanga North-1 exploration well located in Doba basin in southern Chad. The well was drilled to a total depth of 1392 m, and encountered three oil-bearing sand intervals--two in the targeted Upper Cretaceous "YO" sands and one in an untested shallower sand. United Hydrocarbon (100%) is the operator. Asia Pacific China National Offshore Oil Corporation discovered natural gas in the Qiongdongan basin, South China Sea. Well Lingshui 17-2--located in the east Lingshui sag portion of the basin at an average water depth of 1450 m--was drilled and completed to a depth of 3510 m. Lingshui 17-2 encountered a gas reservoir with a total thickness of approximately 55 m. Statoil Australia Theta has drilled and completed the Oz-Alpha 1 exploration well in the southern Georgina basin in the Northern Territory, Australia.
The low price of oil has had an immediate effect in the planning departments of oil companies. They were forced to shift the focus and carefully rank and select only those developments that would ensure profitability in the production of oil and gas. Hence, the field-development projects need to include and consider not only a static or dynamic subsurface characterization but also the production-systems and facilities options, to trigger profitability and establish clear breakeven thresholds. More than ever, the consideration of deep water, tight reservoirs, shale oil, remote locations, or environmentally critical plays is placed under the microscope. Increasingly difficult project economics has delayed or stopped investments that were estimated to be safe and profitable before the price drop.
The development of an offshore oil field is a complex and risky project. One core problem in this task is the selection of a production system that maximizes oil recovery and minimizes investments and operational costs while meeting external, economic, environmental, societal and technological demands in a scenario of uncertainties. Several studies address this problem in the literature; however, they do not consider uncertainties in the initial data neither justify objectively the chosen alternative among other feasible ones. We propose to select an offshore production system using an intelligent system that considers input uncertainties and chooses the best alternative in a rational manner. By comparing the results obtained with previous studies and real scenarios, we conclude that our methodology can obtain the optimal solution in situations where other methods cannot.
In general, Oil Companies need a contract with the government to have legal rights to carry out Exploration and Production (E&P) projects. In this work, we discuss contractual and economic issues in (E&P) sector in Brazil and the dynamics of uncertainties throughout the stages of an E&P project. This study uses Petroleum Resource Management System - PRMS (
In the second part, we use the 12-step integrated decision analysis methodology by
The novel information of this work is the use of the PRMS international standard and the 12-step methodology to not only calculate reserves, but also describe the dynamics of uncertainties throughout a Development Project and to qualify complex contractual and economic issues.
This paper presents information regarding the installation of intelligent-well completions (IWCs) in the Lula and Sapinhoá fields of the Santos basin presalt cluster (SBPSC). The technology is intended to improve reservoir-management capability by using remotely operated flow-control valves and real-time pressure and temperature monitoring for each perforated interval, corresponding to different reservoir zones. The benefits are obtained at the expense of additional challenges for well engineering because well-completion design becomes more complex and overall associated risks increase. The area known as the presalt cluster in the Santos basin is located in ultradeep waters, between 1900 and 2400 m, approximately 290 km from Rio de Janeiro in southeast Brazil.