A major RPSEA ultra-deep water (UDW) strategic theme is early appraisal of a reservoir with minimum drilling in order to reduce the risk associated with planning an economic reservoir development. Deepwater well testing in the Gulf of Mexico (GoM) is not economically viable or practical, primarily due to the high cost of conventional equipment and environmental and safety risks. This paper discusses the results of a research project co-funded by Research Partnership to Secure Energy for America (RPSEA) & Industry "EARLY RESERVOIR APPRAISAL, UTILIZING A WELL TESTING SYSTEM" which incorporated a study utilizing historical deep water production data to show the need for conducting well testing in most Gulf of Mexico (GOM) reservoir discoveries. The project took reservoir data from three major deep water plays. The project analysis and evaluation included eight deep water well testing systems for subsea wells in the Gulf of Mexico (GOM). From the reservoir data sets a complete series of simulated well tests were run: short term and long term tests, interference tests, and injection tests. Also, nodal analyses of the various simulated tests were done. The first part of this paper presents the results and a summary of the analyses. The reservoir modeling led to the design of eight well testing systems that can be used for short-term, long-term, interference, and injection testing. Each system was analyzed for operational feasibility in reference to subsea and surface safety systems, and vessel requirements, with the focus of reducing risks to personnel, the environment, equipment, and complying with all applicable regulations. This paper provides a general oversight to the various well tests. The well test system architectural designs and operational feasibility analysis give all the available options for deep water well testing in regards to downhole, subsea, surface, and vessel requirements, with an extensive focus on safety requirements. Providing this information to industry professionals and operators allows for more accurate decisions when justifying the production capacity and commerciality of a field / reservoir.
Deep water and ultra deep water intervention of wet trees has been a huge challenge for oil and gas producers. Currently, the only realistic way to do intervention is to use a conventional Mobile Offshore Drilling Unit (MODU) or intervention vessel (which is usually a smaller MODU) whether for a simple clean out or re-completing another producing interval. This is an extremely costly venture and the intervention is only scheduled when the economics of the operation are clearly justified.And even when the intervention is approved there is the problem of scheduling a MODU or intervention vessel. Sometimes the intervention can take months before a MODU or intervention vessel is available.There is a new enabling technology, using a Self Standing Riser, (SSR), where a coiled tubing intervention and drilling system could be deployed by a cost effective vessel (not a conventional MODU) with all the coiled tubing and related equipment on the vessel. The SSR design is such that it would attach to the subsea tree and provide the support and a circulation conduit for the coiled tubing to have full circulation capabilities back to the intervention vessel. The vessel, itself, would have station keeping capabilities for a significant period of weather conditions for the Gulf of Mexico. This paper presents the reasons why conventional and subsea coiled tubing approaches have been unable to provide a economically workable solution for coiled tubing intervention and drilling from wet trees in deep water. The paper describes a new system based on a SSR and a cost effective vessel (non MODU) design that could accommodate the coiled tubing equipment, and provide station keeping and support for the operations. The paper will discuss safety issues such as: the reliability and safety of the SSR, well control issues, emergency disconnects, and the event of a drive off by the vessel.Unless, this type of technology is developed and deployed millions of barrels of barrels of oil and gas will remain behind pipe. In other cases, some fields will not be developed because the need for on-going intervention coupled with high capital costs that will not meet the economic threshold to commission the development. 2 SPE 130688
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