No abstract

A natural phase in the life of oilfields is the maturation phase where the field undergoes all or some of situations as decline in pressure, increase in water and/or gas production, and fluid contact movement. Reservoir management practices require identifying these oilfield challenges and coming up with solutions to maximize production from such fields adapted to the uniqueness of the wells and reservoirs in the field. This paper discusses a novel multidisciplinary and rapid screening methodology for identifying well intervention candidates. The methodology adopted to evaluate production increase opportunities was on field and well bases. Geology, Petrophysics, Reservoir Engineering, Production Technology, Production Engineering and Completions Engineering disciplines were involved in this study. The field assessment started with the field production performance review using a production surveillance and forecasting tool. This was combined with a holistic field geological review of the static models and well logs on a shared-earth modelling software and a wellbore-centric data integration and interpretation software respectively. Based on the field assessment review, reservoirs were ranked based on remaining oil in place and cumulative production. Results of the field assessment were then fed into the single well assessment phase where individual well performance was reviewed using the production surveillance and forecasting software. This production surveillance and diagnosis was done vis-a-vis a multidisciplinary workflow of integrating reservoir models, well logs, fluid contact interpretations, pressure data, historical production, completion designs and information from previous workover operations and well surveillance reports. This workflow identified possible candidates where well intervention could be done, the type of well intervention and production enhancement operations that could be deployed, and the order to which the interventions should take place based on cost and potential gains. However, to estimate the incremental production that could be derived from the proposed well interventions, a workflow coupling single well predictive modelling and production systems analysis was done, which was further used to rank the wells. Implementing the recommendations from the rapid screening and ranking workflow resulted in incremental production of 3300 bopd from the few intervention operations executed. The results also validated the predictions made during the rapid screening study. This paper thus demonstrates the added value in a multidisciplinary approach to screening and identifying candidates for well intervention, to extend the life of producing wells and ultimately increase field production.

The Niger Delta land and swamp operators have endured severe hostility, theft, and asset vandalism over time. The offshore assets seem insulated from these incessant thefts due to difficulty accessing the facility and the compactness of the operations resulting in efficient security surveillance. However, this is not the case for land and swamp assets, usually with wide asset footprints resulting from traditional, supposedly easy, and low-cost development concepts. These conventional concepts resulted in wells drilled from multiple locations with multiple flowlines/pipelines crossing many communities and making efficient surveillance a near impossible activity. The attackers usually target movable assets like wellhead accessories, Christmas tree, and flowlines in low-activity areas, and the non-active wells/flowlines are good minimal risk candidates. This act increases the cost of operations and, in most cases, results in environmental pollution because the vandals do not take the necessary precautions as needed for environmentally safe operations. Interestingly, in most cases, these stolen assets find their way into the local market, where they are refurbished and resold to unsuspecting operators. To curb this menace, an opportunity exists for industry collaboration by applying an intelligent supply chain and asset inventory management system. This paper reviews the current asset protection techniques, evaluates the value at risk, and proposes innovative ways of combating theft using digital technology and intelligent asset management techniques.

Over the years horizontal wells have been drilled using the conventional approach. Failure to drill and place the horizontal drain section optimally was becoming a common occurrence especially in a thin reservoir. The search for processes and procedure to mitigate this failure led to the creation of Well Placement (Geosteering) Process. This process was defined (Rogger Griffit 2009) as "The planned interactive placement of the well-bore using geological criteria and real-time measurements". Using geological criteria in real time requires technology capable of adequately delineating the structure and at the same time providing Petrophysical properties of the reservoir in real time. These needs led to development of key Logging While Drilling (LWD) technologies for high angle and horizontal wells. Over the years, the Geosteering methods have evolved based on available LWD technologies. These methods have been classified as (i) Reactive (Basic log correlation), (ii) Proactive (Distance to Boundary) and (iii) Strategic Reservoir mapping). The objective of this paper is to demonstrate how technologies were utilized in Ogini campaign to optimally position the production section of the wells close to the reservoir top, so as to delay onset of water, reduce intervention cost and to increase ultimate recovery. To achieve these objectives despite high risks due to structure and stratigraphy, two well placement methods / technologies were deployed in the landing and within the production section of the reservoir. Real Time Image/dip technology was utilized in the landing section to aid the landing while monitoring the apparent formation dip and a Multilayer Distance –to-Boundary technology (PeriScopeHD*) was used to optimally position 5 horizontal wells close to the tops of each of the target reservoirs in Ogini field.

No abstract