A Production Logging Measurement of Distributed Local Phase Holdup

Halford, F.R.; Mackay, Stuart; Barnett, S.; Petler, John S.

doi:10.2118/35556-ms

Cited by 23 publications

(4 citation statements)

References 1 publication

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“…A number of multi-probe tools such as the fluid profiling tool (FPT) [22], the digital entry and fluid imager tool (DEFT) [23], the Flow Scanner [24], the local impedance flowmeter tool (LIFT) [25], the FLOView Plus [26,27] and the Resistance Array Tool (RAT) [28], etc, were developed and applied by several oil field service companies to measure the water holdup of the oil-water flow in deviated and horizontal wells. Among them, the FPT, DEFT and LIFT consist of only three, four and six conductance probes, respectively.…”

Section: Measurement Science and Technologymentioning

confidence: 99%

Water holdup measurement of oil–water two-phase flow in a horizontal well using a dual-circle conductance probe array

Zhang

Cao

et al. 2016

Meas. Sci. Technol.

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This paper presents a minimum root-mean-square error (RMSE)-based method for a dual-circle conductance probe array to measure the water holdup of an oil-water two-phase flow in a horizontal oil well. The dual-circle conductance probe array consisting of 24 conductance probes, half of which are equidistantly distributed on a 34 mm radius inner circle and the other half on a 48 mm radius outer circle, is used to estimate the oil-water interface and hence the water holdup in the horizontal oil well. For the same water holdup, the number of probes immersed in water may vary with varying the azimuth angle due to the limited number of probes. The limited number of probes and unknown azimuth angle of the probe array in the oil well limit the measurement accuracy of the water holdup. In order to obtain a better water holdup estimate, a water holdup measurement method based on the minimum RMSE was proposed to decrease the effects of the limited number of probes and unknown azimuth angle of the probe array. To verify the proposed method, numerical simulations were carried out and compared with the commonly used equi-weight estimate method; results showed that the RMSE of the water holdup estimates obtained using the proposed method is smaller than that when using the equi-weight estimate method. Experiments were implemented in a 16 m long and 125 mm inner diameter horizontal pipe on an industrial-scale experimental multiphase flow setup in the Daqing Oil Field, China. The RMSEs of water holdup estimates obtained using the proposed and equi-weight estimate methods are 0.0632 and 0.0690, respectively, showing that the proposed method is better than the equi-weight estimate method.

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Section: Measurement Science and Technologymentioning

confidence: 99%

Water holdup measurement of oil–water two-phase flow in a horizontal well using a dual-circle conductance probe array

Zhang

Cao

et al. 2016

Meas. Sci. Technol.

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“…5,6 Certain types of production logging tools measure local and individual phase holdups. 8,9 Some parameters that affect the flow regime are total flow rate, well internal diameter and the physical properties of each fluid phase. [4][5][6] Small changes in wellbore internal diameter (scale buildup, casing patches, casing collars) can increase fluid velocity, and changes in well deviation can cause a dramatic change in the flow regime and on the production logging sensor response.…”

Section: Flow Diagnosis and Holdup Determinationmentioning

confidence: 99%

“…A production logging tool sensor was introduced in the mid 1990's 8,9 to improve handling of some of the interpretation problems related to multiphase flow in wells. The measurements are based on the electrical impedance difference between liquid or gaseous hydrocarbons and water.…”

Section: Conductivity and Electrical Probe Holdup Measurementmentioning

confidence: 99%

Flow Diagnosis and Production Evaluation in High Flowrate Oil-Water Producers Using Optical-Fibre Holdup Sensors

Jackson¹,

Ayan²,

Wakefield³

2001

Proceedings of SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractIn the North Sea (UKCS), Amerada Hess Ltd. is the operator of several oil fields which are developed using subsea technology (Fife, Hudson, Telford etc) and with a fixed platform in the case of the Scott field. In almost all wells, production is above the bubble-point pressure, at a wide range of water-cuts in multilayered reservoir systems. Many of the wells have monobore completions with 5" production tubing and surface flowrates in excess of 15000 stb/d and up to 35000 stb/d. The downhole environment of these wells which comprises of high-velocity multiphase flow, has presented significant problems for conventional production logging sensors and analysis methods to evaluate. Friction and jetting effects on gradiomanometer type tools and small bubble sizes, which can not be detected by electrical probes are the well known complications. To obtain reliable stabilised flow and transient data for diagnosis and production evaluation, a hold-up sensor based on optical principles has been applied. This sensor was recently introduced as a gas hold-up measuring tool. The application described here is the first use of this principle for measuring oil-water hold-up in high flow velocity wells.Flow profile data and interpretation results from several wells are presented. Sensor performance was evaluated by comparing conventional and new generation sensors, including electrical and optical probes. In all cases, the optical probes gave reliable and consistent water holdup values, which were used for the interpretation of the data. Decisions involving water shutoff operations were based on the analysis of these results. We also review pressure and flow transient data recorded during the operations, which has the potential for providing skin factors and reservoir parameters for individual zones in a layered reservoir system.

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“…The prospect of local profiles of three-phase volume fraction is of high potential utility in 'production-logging' applications in petroleum engineering, particularly in horizontal wells where stratified flow conditions are known to exist (Halford et al 1996, Lenn et al 1998, Rounce et al 1999.…”

Section: Introductionmentioning

confidence: 99%

Multi-phase-fluid discrimination with local fibre-optical probes: III. Three-phase flows

Fordham

Ramos

Holmes

et al. 1999

Meas. Sci. Technol.

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Local fibre-optical sensors (or `local probes') for immiscible-fluid discrimination are demonstrated in three-phase (oil/water/gas) flows. The probes are made from standard silica fibres with plane oblique facets polished at the fibre tip, with surface treatment for wettability control. They use total internal reflection to distinguish among drops, bubbles and other regions of fluid in multi-phase flows, on the basis of refractive-index contrast. Dual probes, using two sensors each with a quasi-binary output, are used to determine profiles of three-phase volume fraction in a flow of kerosene, water and air in a pipe. The individual sensors used discriminate oil from `not-oil' and gas from liquid; their logical combination discriminates among the three phases. Companion papers deal with the sensor designs used and quantitative results achieved in the simpler two-phase cases of liquid/liquid flows and gas/liquid flows.

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A Production Logging Measurement of Distributed Local Phase Holdup

Cited by 23 publications

References 1 publication

Water holdup measurement of oil–water two-phase flow in a horizontal well using a dual-circle conductance probe array

Water holdup measurement of oil–water two-phase flow in a horizontal well using a dual-circle conductance probe array

Flow Diagnosis and Production Evaluation in High Flowrate Oil-Water Producers Using Optical-Fibre Holdup Sensors

Multi-phase-fluid discrimination with local fibre-optical probes: III. Three-phase flows

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