Patent Application
20110127032
The invention relates to an alert system and related methods to monitor hydrocarbon production facilities including downhole installations, wellhead, long tie-backs between oil-wells and storage tanks or processing plants.
During the production of hydrocarbons, the hydrocarbons and other by-products flow from the wells drilled into the reservoir to storage facilities or a processing plant. The pipelines and other installations required for this transport are usually referred to as tieback. The flow of hydrocarbon is subject to changing environmental conditions such as changing temperature, pressure, and composition. The changing conditions often cause the precipitation of components out of the main flow.
In this context, management of changing phases like liquids, gases and solids precipitation can be regarded as being fundamental for the assurance of fluid flow along the production systems. Organic (hydrates, waxes, Asphaltenes, naphthanates) or inorganic solids (BaSO4, CaCO3, SrCO3) may obstruct the formation pores and deposit on the wellbore or pipeline walls blocking the fluid production.
In the oil and gas industry, studies are developed to analyze the flow conditions and operations procedures throughout the life of the field. The objective of those studies is to understand the environment, boundary conditions and property changes along the fluid journey from the pore volume of the reservoir to process facilities and point of sales.
To characterize the production, the oil and gas industry is recently focusing, particularly for large subsea developments, on intelligent field solutions and new systems for production control and monitoring as for example presented in: Gudimetla, A. Carroll, K. Havre, C. Christiansen, and J. Canon, “Gulf of Mexico Field of the Future: Subsea Flow Assurance”, OTC 18388, 2006 and G. G. Lunde, K. Vannes, O. T. McClimans, C. Burns, and K. Wittmeyer, “Advanced Flow Assurance System for the Ormen Lange Subsea Gas Development”, OTC 20084, 2009. These recent systems for production management are designed to assist decision making and to provide guidance for the daily operations and future investments. They can perform model-based simulations to represent the production conditions and address potential issues. Generally these systems attempt to address flow assurance problems.
The model-based simulations represent reservoirs, wells, pipelines, production networks and facilities. Those models range from “black oil” to compositional and from steady state to transient. When calibrated with available measurement data as proposed for example in J. Ratulowski, A. Amin, A. Hammami, M. Muhammad, M. Riding, “Flow Assurance and Subsea Productivity Closing the Loop with Connectivity and Measurements”, SPE 90244-MS, 2004 or by A. Amin, E. Smedstad, M. Riding, “Role of Surveillance in Improving Subsea Productivity”, SPE 90209-MS, 2004 and laboratory fluid characterization data such as illustrated in: A. K. M. Jamaluddin, J. Nighswander, N. Joshi, “A Systematic Approach in Deepwater Flow Assurance Fluid Characterization”, SPE 71546-MS, 2001, such models can be used to estimate fluid properties throughout the system.
Software tools to assist the assessment of potential flow assurance problems are commercially available by many vendors and include for example steady-state fluid flow simulators such as PIPESIM™, transient fluid flow simulators such as OLGA™, fluid analysis software designed to predict the thermodynamic precipitation point of waxes and asphaltenes such as dbrSOLIDS™, and integrated asset modeler simulators such as Avocet™ IAM capable of modeling the fluid flow from the reservoir through to refining stages. Those tools allow production engineers to understand potential system problems, such as flow restrictions due to solids precipitation and deposition.
The use of the model-based simulation to create operation profiles is well known in the industry, these profiles are used to evaluate the risk of solids precipitation and deposition along the flow path. However in the light of the known methods it is seen as an object of the present invention to provide a method of monitoring different types of possible solids from each fluid footprint, and at different timeframes.
The present invention provides a method for monitoring a fluid flow in a flow line from a location in a subterranean reservoir to a surface storage or production facility using the steps of employing sensors located in the wellbore and along the flow line for monitoring flow conditions, establishing parameters which determine the precipitation of solid components from the fluid flow, setting alert parameters relating to the precipitation parameters, and determining an operating profile representative of present conditions along the flow line, wherein the precipitation parameters, the alert parameters and the operating profile and extrapolation of the operating profile are represented in a single parameter space.
The invention provides in a preferred embodiment a method of representing important flow assurance parameter as linked to the precipitation of organic and/or inorganic flow components in a compact representation. This representation facilitates the setting, the monitoring and the display of alarm thresholds.
In another preferred embodiment, the invention includes the use of subterranean sensors to update flow models of the reservoir so as to provide a long-term projection or extrapolation of the operating profile. In turn, this extrapolation in combination with the other features of the present invention can be used to define operating guidelines which reduce or avoid precipitation.
These and other aspects of the invention are described in greater detail below making reference to the following drawings.
In the following example
The system can be implemented using known subsea and surface devices as described in the above cited documents and particularly in G. Deans, R. MacKenzie, “Enabling Subsea Surveillance: Embracing “True Production Control” With An Open Architecture Subsea Monitoring And Control System”, Conference Subsea Controls and Data Acquisition 2006: Controlling the Future Subsea, Jun. 7-8, 2006, Neptune, France SCADA-06-074.
Using such an infrastructure of sensors and other monitoring devices, different commercial software packages as referred to above can be used to calculate the fluid multiphase envelope and operating profiles. A schematic example of phase envelopes combined with an operating profile in a P-T or thermo-hydraulic plot is shown in
A more complex example is shown in
In
In
The operating profiles 340 and their extrapolations 341, 342 in time of
The first extrapolated curve 341 can be referred to as a daily production look-ahead operating profile. This profile is taken as an example of a short-term look-ahead scenario for production operations surveillance as generated best by a transient simulation model such as OLGA. It provides an overview of the possible event on the near future. On this profile the look-ahead or extrapolation time step should be relatively short ranging for example from minutes to days. For this short period the conditions on the reservoir pressure and temperature should not change significantly. Hence the model can be limited to the extrapolation of the operating conditions from the wellhead and beyond.
In case the short-term look-ahead scenario touches the alarm boundaries, the system is capable of indicating the need for remedial action. The alert enables an operator to schedule remedial action ahead of time, hence avoiding or reducing potential bottlenecks or loss of production.
The second extrapolated curve 342 can be referred as reservoir management look-ahead operating profile. This profile is taken as an example of a long-term look-ahead scenario and is generated from an integrated simulator by coupling a reservoir model with the production system model. The reservoir model is a geological model of the subsurface reservoir 10 and can be built by combining available seismic, logging and other geophysical data using standard software tools such as Petrel™. To model the fluid flow in the reservoir it may be necessary to combine the reservoir model with a flow modeling software such as Eclipse™. The long-term look-ahead scenario seeks to encompass changes in the reservoir and hence its time steps are measured typically in weeks or months or even years. It can be scheduled in line with full field reviews or assessments, which require an extended forecast of the field operations based on the future conditions. A benefit of long-term look-ahead scenario is expected to be the capability of changing production conditions such that precipitation is reduced or avoided without having to resort to remedial actions, hence enabling preventive actions.
All the data acquired from field instrumentation and sensors and generated by the simulators as described above are fed into a data hub that assures the correct data flow between the software packages to monitor the selected parameters and regulate the surveillance alarms. A flow chart listing components and steps of the above example of the invention is illustrated in
The system as described by
The simulators 43 used for this example are combining steady-state simulator and transient state simulator.
The system has three main operating modes. The first monitors the operating profile in real-time to generate alerts, if the real-time operating profiles crosses a precipitation curve. The second mode monitors the crossing of the real-time operating profile with any of the alerts curves or thresholds defined above. In this mode, alarms can be raised by the system and a short-term look-ahead simulation can be initiated.
Further components include data-driven models such as neural networks 45 to adjust the system based on past conditions and a reservoir simulator 46 to provide a long-term look-ahead simulation of the operating profile. The long-term look-ahead simulation can be part of the decision making process to change well and production parameters such that the operating profile remains within the desired limits as defined by solid precipitation.
The above system includes a static configuration part which defines an operational space the boundaries of which are at least partly defined by the solid precipitation curves. It defines the parameter space in which the operating profile can change without triggering remedial action. In another variant, the static part can be at least partially replaced by a constant update as provided by sensors performing a real-time compositional flow analysis.
The system also has a second dynamic component, the monitoring part, which receives field data and updates simulation results to determine real-time and extrapolated operating profiles and display these profiles with the operational space as defined by the configuration part. A third component, the diagnostic part, is initiated or triggered boundary condition violation leading to decisions on short-, medium- or long term remedial action and, if required, to a model re-calibration. By its nature this latter part is invoked sporadically as alert thresholds or precipitation boundaries are approached or crossed by the operating profile.
While the invention is described through the above exemplary embodiments, it will be understood by those of ordinary skill in the art that modification to and variation of the illustrated embodiments may be made without departing from the inventive concepts herein disclosed. Moreover, while the preferred embodiments are described in connection with various illustrative processes, one skilled in the art will recognize that the system may be embodied using a variety of specific procedures and equipment and could be performed to evaluate widely different types of applications. Accordingly, the invention should not be viewed as limited except by the scope of the appended claims.
