Real-time Production Optimization in the Okume Complex Field, Offshore Equatorial Guinea

Omole, Oluwole Ayodotun; Saputelli, Luigi; Lissanon, Janvier Symphorien; Nnaji, Obiageli; González, Fabio; Wachel, Georgie Ann; Boles, Kim Bruce; Leon, Edicson; Parek, Bimal; Nguema, Nicolas; Borges, J.; Hadjipieris, Pieris

doi:10.2118/144195-ms

Cited by 14 publications

(1 citation statement)

References 9 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Recently, numerous projects have adopted the iDOF concepts, implemented with the goal of achieving total asset awareness and optimize operations throughout the field lifecycle (Saputelli et al 2003;Mochizuki et al 2009;Abdulaziz et al 2010;Perrons 2010;Omole et al 2011).…”

Section: Introductionmentioning

confidence: 99%

Effective Well Management in Sabriyah Intelligent Digital Oilfield

et al. 2013

Self Cite

View full text Add to dashboard Cite

Oil production from North Kuwait carbonate reservoirs are challenging because of factors, such as high permeability streaks, poor microscopic sweep efficiency, and low mobility ratios, all of which can dramatically impair production rates and oil recoveries. Despite tremendous efforts related to waterflood research, oil recovery in carbonates typically remains low. New technology and approaches are required to increase and sustain oil production to access and drain immense amounts of remaining oil-in-place.This paper presents the results of collaborative work procedures applied to a selective number of wells to increase production performance in the Sabriyah Mauddud field pilot under the Kuwait Integrated Digital Field (KwIDF) project umbrella. KwIDF is part of a comprehensive strategy undertaken by an operator to enhance overall oil production by the application of digital oilfield (DOF) concepts, which involves (1) well instrumentation to provide enhanced real-time data availability, (2) upgraded power and communications infrastructure to support field instrumentation and control real-time data, (3), creating collaborative decision centers to enhance asset team processes across physically separate locations, and (4) providing a platform to increase effectiveness through automating work processes and to shorten observation-to-action cycle time.The Sabriyah KwIDF pilot involves 44 producer and five injector wells producing about 7% of total Sabriyah field production. The main objective of this effort was to maximize and sustain oil rates and reduce well decline while honoring safe well operating envelope constraints. As a result of this effort, production gains have been certified in 10 wells of the pilot area to date. This success has been achieved by carefully analyzing past performance and adjusting well settings to realtime production conditions using the operator's digital infrastructure.This paper describes how this optimization methodology provides improvements to short-term production rates while honoring safe well operating envelope and presents case histories illustrating the benefits from the automated workflows and collaborative decision approach. The average sustained oil gain was 395 BOPD, or 37%. The total sustained oil gain reached 3,949 BOPD (34%), with a cumulative production gain of 756 thousand barrels for the evaluation period.

show abstract

Section: Introductionmentioning

confidence: 99%

Effective Well Management in Sabriyah Intelligent Digital Oilfield

et al. 2013

Self Cite

View full text Add to dashboard Cite

show abstract

Transferring Intelligent-Well-System Triple-Gauge Data Into Real-Time Flow Allocation

Sun

Omole

Saputelli

et al. 2012

SPE Drilling &Amp; Completion

View full text Add to dashboard Cite

Summary Knowing the exact flow allocation for each controlled zone is important for well optimization and the management of an intelligent well system (IWS). For two-zone IWS producers, a broadly accepted downhole gauge configuration uses the triple-gauge system, where two gauges give the upstream-side pressure/temperature (P/T) of the two downhole control valves and one gauge gives the P/T inside tubing of the commingled fluid [Baker Hughes IWS installation (2012) and Halliburton-WellDynamics IWS installation (2012) databases]. Theoretically, this configuration gives the P/T boundary conditions between the two valves and the gauge carrier, where flow allocations can be solved numerically, on the basis of the gauge readings and control-valve settings. However, from what we have seen in the past 10 years of IWS applications, only a few have published successful application cases regarding this topic. Is this an indication that a large number of two-zone triple-gauge IWS wells are operating in the low-confidence region of the two zone's production flow allocations? In this work, a comprehensive hydraulic model has been developed to address this topic. This paper will discuss a recent application of such a model to estimate the flow allocations of an existing two-zone deepwater IWS oil producer. The well began production in 2007. A total of 1,362 daily triple-gauge data points are available for this study, where the monitored P/T data indicate that the well was flowed in multiphase conditions at downhole for a large percentage of its production life. Verification was completed by comparing the predicted flow-allocation results with this well's measured total rates and daily-allocation rates. Further comparisons of the zonal allocations, between the model calculated results vs. the zonal-reservoir deliverability-study predicted results, were also provided. These comparisons showed a good match between the predicted results, measured data, and the available reservoir-study results. Descriptions of key factors to address the accuracy of the method have been provided, including compensated differential pressure, multiphase choke model, choke-discharge coefficient, and fluid pressure/volume/temperature (PVT) behavior impact. Sun's modified multiphase choke model was proposed in this study. The authors believe it will be more suitable for downhole valve operating and multiphase-flow conditions. This case study has proven a very promising independent solution for continuous well-rate estimation, with the solution based purely on choke-pressure drops and intelligent well-valve positions. The downhole monitoring P/T is normally based on seconds, which means that intelligent well-flow allocations can be calculated in real time without installing downhole venturi flowmeters that may add completion cost. In addition, a venturi flowmeter provides a smaller ID profile for the completion strings above/below it, which is inconvenient for future potential wellbore interventions. This solution brings measurable benefits for those IWS wells with no downhole flowmeters when taking into account the time and effort spent on periodic production tests, reservoir/well deliverability studies for production allocations, and potential production loss during the production tests.

show abstract

Inflow Performance Identification and Zonal Rate Allocation from Commingled Production Tests in Intelligent Wells—Offshore West Africa

Saputelli

Omole

González

et al. 2011

SPE Annual Technical Conference and Exhibition

View full text Add to dashboard Cite

The main objective of a production well test is to assist in the identification of reservoir and well parameters needed for regulatory accounting, well surveillance, and asset management purposes. Interpreted information is used to drive decisions on production enhancement, operations optimization, and field-development plans. However, uncertain results may occur when wells are produced from multiple reservoirs. Currently, the industry approach is to allocate well and reservoir parameters based on known petrophysical data, offset well information, and zonal well tests. When possible, testing by difference is commonly performed to control one or more zones; however, this process may result in significant production losses with poor concluding results, especially when zonal interference is vital to a well's operating point (e.g., intelligent wells in a waterflood field). A methodology was developed to consistently identify reservoir and well-performance parameters from wells produced under commingle conditions from multiple reservoir zones by leveraging available real-time data. This methodology was successfully applied in a field located in offshore West Africa, a waterflooded field with nine intelligent wells. The methodology integrates surface well-test rates, pressures, and downhole triple-gauge data. Collected data is validated via a rigorous history calibration process of an integrated production model consisting of an analytical reservoir, well, downhole and surface chokes, and pipeline models. The calculated parameters (e.g., zonal rates, productivity index, reservoir pressure, gasoil ratio, and water cut) are the result of an error minimization between calculated variables and measured field data. This paper presents applications of this methodology for two production tests of a single dry-tree well with individually controlled reservoir zones. Benefits of the above application include a 90% reduction of the time required to perform a similar analysis, reduced uncertainty in rate allocation and reservoir parameters, and better understanding of the likely production from every reservoir zone. Because well and reservoir parameters are allocated to individual layers, the resulting rate allocation satisfies all sensor data and physical models, and therefore the uncertainty of the allocation is reduced. In addition, the application provides the basis for rate allocation to multiple zones in real time when well tests are not available.

show abstract

Real-time Production Optimization in the Okume Complex Field, Offshore Equatorial Guinea

Abstract: REV201300923  IPM models are now frequently continuously used in the decision making process and to generate improved asset production opportunities.

Cited by 14 publications

References 9 publications

Effective Well Management in Sabriyah Intelligent Digital Oilfield

Effective Well Management in Sabriyah Intelligent Digital Oilfield

Transferring Intelligent-Well-System Triple-Gauge Data Into Real-Time Flow Allocation

Inflow Performance Identification and Zonal Rate Allocation from Commingled Production Tests in Intelligent Wells—Offshore West Africa

Contact Info

Product

Resources

About