Detection of scale deposition using distributed temperature sensing

Fajhan H. Almutairi, David R. Davies

Research output: Chapter in Book/Report/Conference proceedingConference contribution

Abstract

The rapid deployment of distributed temperature sensor (DTS) systems in the oil and gas E&P industry provided the engineers with large amount of real-time, downhole data. Although the basic principles for DTS operations are simple, the interpretation of the downhole data presents a challenge for the production engineer. Inflow profiling has been promoted as the prime reason for the installation of DTS systems, though DTS data are currently used in all aspects of production engineering. The differences between the thermal properties of oil, gas and water allow the detection of unwanted fluids using DTS. Monitoring of the produced fluid temperature allow the engineer to prevent the formation of wax and hydrates, ensuring effective flow assurance. This paper examines a novel DTS application by analyzing the effect of scale deposition on the temperature profile of a conventional producing well. The low thermal conductivity of scale deposits increases the temperature of the producing fluid in the scaled region. A sensitivity study has examined the expected range of temperature increase caused by scale deposition to determine the conditions under which the flowing fluid temperature increase is a maximum. Low to moderate production rate environments with low water production yield the greatest increase in flowing fluid temperature when scale is present. The thermal insulation provided by the scale causes a unique temperature profile. Quantitative analysis allows the scale thickness to be determined. Copyright 2008, Society of Petroleum Engineers.

Original languageEnglish
Title of host publicationSociety of Petroleum Engineers - 9th International Conference on Oilfield Scale 2008 - "Managing Scale Through the Field Lifetime"
Pages25-37
Number of pages13
Publication statusPublished - 2008
Event9th International Conference on Oilfield Scale 2008 - "Managing Scale Through the Field Lifetime" - Aberdeen, United Kingdom
Duration: 28 May 200829 May 2008

Conference

Conference9th International Conference on Oilfield Scale 2008 - "Managing Scale Through the Field Lifetime"
CountryUnited Kingdom
CityAberdeen
Period28/05/0829/05/08

Fingerprint

Temperature sensors
Fluids
Engineers
Temperature
Temperature scales
Production engineering
Thermal insulation
Waxes
Gas oils
Hydrates
Water
Thermal conductivity
Thermodynamic properties
Deposits
Monitoring
Chemical analysis
Gases
Industry

Cite this

Almutairi, F. H., & Davies, D. R. (2008). Detection of scale deposition using distributed temperature sensing. In Society of Petroleum Engineers - 9th International Conference on Oilfield Scale 2008 - "Managing Scale Through the Field Lifetime" (pp. 25-37)
Almutairi, Fajhan H. ; Davies, David R. / Detection of scale deposition using distributed temperature sensing. Society of Petroleum Engineers - 9th International Conference on Oilfield Scale 2008 - "Managing Scale Through the Field Lifetime". 2008. pp. 25-37
@inproceedings{27dd47d0d35a4b89a0f2658f06c14d2b,
title = "Detection of scale deposition using distributed temperature sensing",
abstract = "The rapid deployment of distributed temperature sensor (DTS) systems in the oil and gas E&P industry provided the engineers with large amount of real-time, downhole data. Although the basic principles for DTS operations are simple, the interpretation of the downhole data presents a challenge for the production engineer. Inflow profiling has been promoted as the prime reason for the installation of DTS systems, though DTS data are currently used in all aspects of production engineering. The differences between the thermal properties of oil, gas and water allow the detection of unwanted fluids using DTS. Monitoring of the produced fluid temperature allow the engineer to prevent the formation of wax and hydrates, ensuring effective flow assurance. This paper examines a novel DTS application by analyzing the effect of scale deposition on the temperature profile of a conventional producing well. The low thermal conductivity of scale deposits increases the temperature of the producing fluid in the scaled region. A sensitivity study has examined the expected range of temperature increase caused by scale deposition to determine the conditions under which the flowing fluid temperature increase is a maximum. Low to moderate production rate environments with low water production yield the greatest increase in flowing fluid temperature when scale is present. The thermal insulation provided by the scale causes a unique temperature profile. Quantitative analysis allows the scale thickness to be determined. Copyright 2008, Society of Petroleum Engineers.",
author = "Almutairi, {Fajhan H.} and Davies, {David R.}",
year = "2008",
language = "English",
isbn = "9781605603414",
pages = "25--37",
booktitle = "Society of Petroleum Engineers - 9th International Conference on Oilfield Scale 2008 - {"}Managing Scale Through the Field Lifetime{"}",

}

Almutairi, FH & Davies, DR 2008, Detection of scale deposition using distributed temperature sensing. in Society of Petroleum Engineers - 9th International Conference on Oilfield Scale 2008 - "Managing Scale Through the Field Lifetime". pp. 25-37, 9th International Conference on Oilfield Scale 2008 - "Managing Scale Through the Field Lifetime", Aberdeen, United Kingdom, 28/05/08.

Detection of scale deposition using distributed temperature sensing. / Almutairi, Fajhan H.; Davies, David R.

Society of Petroleum Engineers - 9th International Conference on Oilfield Scale 2008 - "Managing Scale Through the Field Lifetime". 2008. p. 25-37.

Research output: Chapter in Book/Report/Conference proceedingConference contribution

TY - GEN

T1 - Detection of scale deposition using distributed temperature sensing

AU - Almutairi, Fajhan H.

AU - Davies, David R.

PY - 2008

Y1 - 2008

N2 - The rapid deployment of distributed temperature sensor (DTS) systems in the oil and gas E&P industry provided the engineers with large amount of real-time, downhole data. Although the basic principles for DTS operations are simple, the interpretation of the downhole data presents a challenge for the production engineer. Inflow profiling has been promoted as the prime reason for the installation of DTS systems, though DTS data are currently used in all aspects of production engineering. The differences between the thermal properties of oil, gas and water allow the detection of unwanted fluids using DTS. Monitoring of the produced fluid temperature allow the engineer to prevent the formation of wax and hydrates, ensuring effective flow assurance. This paper examines a novel DTS application by analyzing the effect of scale deposition on the temperature profile of a conventional producing well. The low thermal conductivity of scale deposits increases the temperature of the producing fluid in the scaled region. A sensitivity study has examined the expected range of temperature increase caused by scale deposition to determine the conditions under which the flowing fluid temperature increase is a maximum. Low to moderate production rate environments with low water production yield the greatest increase in flowing fluid temperature when scale is present. The thermal insulation provided by the scale causes a unique temperature profile. Quantitative analysis allows the scale thickness to be determined. Copyright 2008, Society of Petroleum Engineers.

AB - The rapid deployment of distributed temperature sensor (DTS) systems in the oil and gas E&P industry provided the engineers with large amount of real-time, downhole data. Although the basic principles for DTS operations are simple, the interpretation of the downhole data presents a challenge for the production engineer. Inflow profiling has been promoted as the prime reason for the installation of DTS systems, though DTS data are currently used in all aspects of production engineering. The differences between the thermal properties of oil, gas and water allow the detection of unwanted fluids using DTS. Monitoring of the produced fluid temperature allow the engineer to prevent the formation of wax and hydrates, ensuring effective flow assurance. This paper examines a novel DTS application by analyzing the effect of scale deposition on the temperature profile of a conventional producing well. The low thermal conductivity of scale deposits increases the temperature of the producing fluid in the scaled region. A sensitivity study has examined the expected range of temperature increase caused by scale deposition to determine the conditions under which the flowing fluid temperature increase is a maximum. Low to moderate production rate environments with low water production yield the greatest increase in flowing fluid temperature when scale is present. The thermal insulation provided by the scale causes a unique temperature profile. Quantitative analysis allows the scale thickness to be determined. Copyright 2008, Society of Petroleum Engineers.

UR - http://www.scopus.com/inward/record.url?scp=53349096245&partnerID=8YFLogxK

M3 - Conference contribution

SN - 9781605603414

SP - 25

EP - 37

BT - Society of Petroleum Engineers - 9th International Conference on Oilfield Scale 2008 - "Managing Scale Through the Field Lifetime"

ER -

Almutairi FH, Davies DR. Detection of scale deposition using distributed temperature sensing. In Society of Petroleum Engineers - 9th International Conference on Oilfield Scale 2008 - "Managing Scale Through the Field Lifetime". 2008. p. 25-37