Digital oil field (DOF) in the upstream industry has gained momentum in the last few years and has transformed from being solely a vision to actual projects that have measurable value. The ultimate goal in DOF projects is an integrated approach toward decision making and control of asset management in relevant time. This paper describes the successful methodology adopted for implementing the i-field™ program (i-field is a trademark of Chevron Corporation) in Agbami-namely, identification, prioritization, and implementation of relevant workflows.The Agbami field, located in deepwater offshore Nigeria, is a subsea development that incorporates crestal gas and peripheral water injection. It is located in approximately 1500 m of water depth and consists of a 38-well development program to be implemented in three phases. The well completion incorporates intelligent well completions (IWCs)-downhole flowmeters, pressure and temperature gauges, and interval-control valves (ICVs). These downhole accessories are managed using electric and hydraulic controls/instrumentation, with subsurface, subsea, and topside data acquired and transmitted to a central data historian on the floating production, storage, and offloading (FPSO) unit in relevant time. The implementation of a robust architecture for a data-and informationmanagement system involving acquisition, processing, storage, and replication (from offshore to onshore) is conceived to be the foundation upon which asset-management workflows are implemented.The expected benefits from implementing the i-field program in Agbami include reduction in lost production opportunity (LPO) through proactive asset management, better long-term reservoir management through time-line management of injection-and production-rate balancing, increased efficiency and reliability through guided workflows, improved ultimate recovery, and better overall performance from standardization of base business work processes. The real value of implementing i-field initiatives in Agbami lies not only in the return on investment but also in providing a benchmark for capturing the value of other assets. Based on field experience, this paper discusses the approach toward value realization of the i-field system, including change-management strategy for end-user acceptance. Critical success factors and lessons learned during deployment are also presented.
Digital oil field (DOF) in the upstream industry has gained momentum in the last few years and has transformed from being solely a vision to actual projects that have measurable value. The ultimate goal in DOF projects is an integrated approach towards decision making and control of asset management in relevant time. This paper describes the successful methodology adopted for implementing i-field™ in Agbami-namely, identification, prioritization, and implementation of relevant workflows.The Agbami field, located in deepwater offshore Nigeria, is a subsea development that incorporates crestal gas and peripheral water injection. It is located in ~1,500 m of water depth and consists of a 38 well-development program to be implemented in three phases. The well completion incorporates intelligent well completions (IWC)-downhole flow meters, pressure and temperature gauges, and interval control valves. These downhole accessories are managed using electric and hydraulic controls/instrumentation with subsurface, subsea, and topsides data acquired and transmitted to a central-data historian on the FPSO in relevant time. The implementation of a robust architecture for a data and information management system involving acquisition, processing, storage, and replication (from offshore to onshore) is conceived to be the foundation upon which asset management workflows are implemented.The expected benefits from implementing i-field™ in Agbami include reduction in lost production opportunity (LPO) through proactive asset management, better long-term reservoir management through timeline management of injection and productionrate balancing, increased efficiency and reliability through guided workflows, improved ultimate recovery, and better overall performance from standardization of base business work processes. The real value of implementing i-field™ initiatives in Agbami is not only justified by the return on investment but also by providing a benchmark for capturing the value by other assets. Based on field experience, this paper discusses the approach towards value realization of the i-field™ system, including changemanagement strategy for end-user acceptance. Critical success factors and lessons learned during deployment are also presented. SPE 127691The Agbami i-field™ opportunity was to design and implement by first oil, an integrated, multi-disciplinary series of work processes, tools, and technologies that will enable the asset team to make better and timely decisions, thereby sustaining the production plateau and enhancing the value of the Agbami asset. This goal was achieved in July 2008, when Agbami achieved first oil and several priority workflows were implemented to support start-up and ramp-up phases 1 . Subsequently, several other workflows were implemented to enable and support well-reliability monitoring, reservoir management, and production optimization work processes.This paper is a sequel to the earlier work 1 describing the i-field™ initiatives in Agbami. In addition to the vision and methodology adopted for...
Application of Intelligent Well Completion (IWC) technology has continued to grow within the industry even in the face of perceived risks associated with installation and longevity of the system. In Agbami, where 80% of the development wells are planned with IWC installations, understanding these risks played a key role in justifying intelligent completions. This paper will present the methodology used to quantify the realizable value from zonal control and data acquisition, and review the execution performance for the initial IWC wells.The Agbami field is Chevron's first operated deepwater asset in offshore Nigeria. It is located 70 miles offshore of the Niger Delta in ~5000 feet of water. The subsurface is characterized by a double-plunging anticline structure with a thrust fault along the main axis and multiple flank normal faults dividing the three major reservoirs into five or six main producing areas. Each major reservoir is vertically subdivided into 3 or more sub-reservoirs. The field is being developed with 38 wells, consisting of 20 producers, 12 water injectors and 6 gas injectors spread over 3 development drilling stages. Pressure maintenance will be via peripheral Water Injection and produced Gas Re-injection. The production facilities include full Subsea infrastructures (trees, manifolds & flowlines) producing to a Floating Production, Storage, and Offloading vessel (FPSO).The Agbami wells are typically completed in multiple zones of the same reservoir. The completed zones are geologically in pressure equilibrium, but vertical and lateral/cross-fault connectivity under dynamic conditions is still very uncertain. Given this uncertainty, the water and gas flood-fronts are likely to advance at different rates through the reservoir. To optimize field performance and recovery, Intelligent Completions with downhole control valves are being installed in Agbami wells. The system will provide zonal information and control of production and injection into the completed sub-reservoir zones.
The Agbami project offshore Nigeria uses a suite of production monitoring, control and optimization tools and techniques. The project uses an intelligent well completion whereby production and injection is optimized from the well through the relevant time feedback of information from downhole pressure, temperature gauges and flow meters. A downhole interval control valve provides the capability to control production and injection, thus maximizing the recovery of hydrocarbon from the field. The field consists of both injection and production wells. Oil production is from multiple zones, which are co-produced into the wellbore. Due to the complexities of the subsea production and injection manifold and riser configurations, downhole flow meters are used for production and injection allocation purposes for the different formations within the reservoir. Agbami Field utilizes an in-well flow meter. The technology is based on a differential pressure full bore electronic flow meter which is first in the industry. The sensors utilized are high resolution pressure and temperature sensors. In order to demonstrate the robustness and the capability of the flow meter for production and injection allocation purposes, a series of flow loop qualification testing have been designed. One of the tests used a mixture of oil and water in a test facility to demonstrate the capability of the flow meter to accurately measure oil and water production. This test is probably the first of its kind using a test structure over 100 ft in height. The paper will outline the aims, the preparation requirements, the conducted test and the resulting qualification testing. It will also demonstrate how the results will assist in the production allocation and optimization of recovery from the field. Through this testing, the operator demonstrated commitment to the intelligent well completion initiative as well as the provision of an accurate method of allocating production using in-well flow meter and pressure and temperature gauges. Introduction The Agbami project is located 70 miles offshore Nigeria in approximately 5,000 feet of water in the central Niger Delta. At $7 billion, this project in OML Block 127 and 128 is poised to be Nigeria's largest deepwater development. This field was discovered in 1996 when Texaco and Famfa were granted the rights to the 617,000 acre block 216 where the reserves were proven in 1998. Chevron is the operator, with a 68.15% interest; Statoil has an 18.85% interest (which it took in 2004) and the other 13% is held by Petrobras. The field is operated under the terms of two deepwater production-sharing contracts (PSC) and a technical sharing agreement (TSC) between Texaco and Famfa.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractLarge, deepwater fields with a limited number of wells may require intelligent well systems to maximize production capacity under facility constraints. Agbami field, a highlydipping reservoir with many producing zones and few wells, will use intelligent well systems to manage fluid fronts in a gravity-stable recovery scheme.The reservoir has many producing zones with high-quality rock properties. Intelligent well systems, which consist of interval control valves (ICVs) and many sensors, will be used to monitor, analyze, and control (MAC) injection and production at the zonal level. Analysis of sensor data will allow operations to estimate well capacity and calculate actual flow rates. Decisions for operational control will be made based on the data analysis, the results of which will be used to optimize overall field performance and maximize financial returns.In this study, a strategy was developed to maximize Agbami's full-field rate capacity in three production phases; ramp-up, plateau, and decline. Rate capacity response was investigated at the field, well, and zonal levels, including operational and reservoir uncertainties; e.g., injector plugging, well downtime, permeability variation, and fault-seal settings. Using a combination of scenario-testing and mitigation strategies, several key decisions were made, including the number and placement location of ICVs based on well type, range of production and injection rates, and zonal allocation.
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