Fibre Optic Sensing For Improved Wellbore Production Surveillance

Horst, Juun van der; Boer, H.; Panhuis, Peter in ‘t; Wyker, Brendan; Kusters, Roel; Mustafina, Daria; Groen, Lex; Bulushi, N.; Mjeni, Rifaat; Awan, Kamran; Rajhi, Salma Mohammed; Molenaar, Mathieu M.; Reynolds, Alan; Paleja, Rakesh; Randell, David; Bartlett, Richard; Green, Kevyn

doi:10.2523/17528-ms

Cited by 14 publications

(2 citation statements)

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“…An interesting option that could aid identifiability and input design is the possibility to gather additional information about the aquifer or reservoir with a method known as Fiber-Optic Distributed Acoustic Sensing ( [45,46]).…”

Section: Discussionmentioning

confidence: 99%

Optimal input experiment design and parameter estimation in core-scale pressure oscillation experiments

Potters

Mansoori

Bombois

et al. 2016

Journal of Hydrology

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International audienceThis paper considers Pressure Oscillation (PO) experiments for which we find the minimum experiment time that guarantees user-imposed parameter variance upper bounds and honours actuator limits. The parameters permeability and porosity are estimated with a classical least-squares estimation method for which an expression of the covariance matrix of the estimates is calculated. This expression is used to tackle the optimization problem. We study the Dynamic Darcy Cell experiment set-up (Heller et al., 2002) and focus on data generation using square wave actuator signals, which, as we shall prove, deliver shorter experiment times than sinusoidal ones. Parameter identification is achieved using either inlet pressure/outlet pressure measurements (Heller et al., 2002) or actuator position/outlet pressure measurements, where the latter is a novel approach. The solution to the optimization problem reveals that for both measurement methods an optimal excitation frequency, an optimal inlet volume, and an optimal outlet volume exist. We find that under the same parameter variance bounds and actuator constraints, actuator position/outlet pressure measurements result in required experiment times that are a factor fourteen smaller compared to inlet pressure/outlet pressure measurements. This result is analysed in detail and we find that the dominant effect driving this difference originates from an identifiability problem when using inlet–outlet pressure measurements for joint estimation of permeability and porosity. We illustrate our results with numerical simulations, and show excellent agreement with theoretical expectations

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Section: Discussionmentioning

confidence: 99%

Optimal input experiment design and parameter estimation in core-scale pressure oscillation experiments

Potters

Mansoori

Bombois

et al. 2016

Journal of Hydrology

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“…As data acquisition easily occurs with 5,000 or 10,000 pulses per second it is possible to record strain variations or 'acoustic vibrations'. DAS applications currently include Hydraulic Fracture Monitoring, Vertical Seismic Profiling, Gas lift Surveillance and Injection Conformance Monitoring & Production Conformance Monitoring [2,3,4,5,6,7,8,9,10,11].…”

Section: Introductionmentioning

confidence: 99%

Fiber Optic Based Reservoir Surveillance for Injection Conformance Monitoring and Production Profiling in EOR Fields

Hemink

Groen

Deitrick

et al. 2016

Day 2 Tue, March 22, 2016

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Petroleum Development Oman (PDO) is increasingly relying on Enhanced Oil Recovery Technologies to optimize production. Successful implementation and operation of polymer flood field developments in Oman involves dealing with a variety of risks that can impact injection conformance, sweep efficiency, production, and surface facilities. The subsurface risks predominantly relate to Fracture propagation, Vertical Conformance and Areal Conformance. Mitigation of these risks is key to enabling economical field developments and requires implementation of adequate surveillance and control measures.Conventional technologies that may be able to acquire the required surveillance data, like production logging, can be costly and/or give unreliable results. In addition, the extreme high well density makes well entries difficult and complicates conventional surveillance. Fiber Optic Surveillance Technologies are most favorable as an alternative because of their potential applicability in water and polymer injectors as well as oil producers; their non-intrusive nature reduces HSSE exposure; and their low cost and automated on-demand time-lapse surveillance potential.Shell and PDO have collaborated on the development of robust interpretation workflows for Distributed Temperature Sensing (DTS) warm back surveys in mature injector wells, and Distributed Acoustic Sensing (DAS) for injection profiling in polymer injector wells and production profiling in oil producers. Data were gathered during various field campaigns as well as in controlled polymer flow loop experiments.This paper presents one successful and one less successful DTS warmback survey conducted in a water and a polymer injector well, and also the recommendations to improve the quality of warmback surveys. Three other datasets are presented, the first two relate to DAS injection conformance monitoring where DAS was acquired in a polymer injector well and used, together with a PLT survey during the water injection periods, to assess the change in injection conformance. The last test relates to a DAS acquisition in an oil producer well equipped with a Progressive Cavity Pump.

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