Annular Packer Fluids for Paraffin Control: Model Study and Successful Field Application

Ashford, J. D.; Blount, C.G.; Marcou, J.A.; Ralph, Joseph M.; Skaalure, Eric W.

doi:10.2118/19730-pa

Cited by 21 publications

(13 citation statements)

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“…Thermal stability was also questionable at the working temperatures. More-advanced gelatinous oil-based fluids (Son et al 1983;Yousif et al 1994;Ashford et al 1990;Suarez et al 1995) have been developed with relative thermal conductivity of this type of fluids approximately 13% that of water and found applications in steam injection and paraffin control. However, current and future environmental restrictions could limit its application.…”

Section: History Of Thermal Insulation In the Oil Fieldsmentioning

confidence: 99%

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New Trend in Oilfield Flow-Assurance Management: A Review of Thermal Insulating Fluids

Wang¹,

Qu²,

Javora³

et al. 2009

SPE Production &Amp; Operations

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Flow assurance has been one of the major considerations in deepwater completion design, in which undesired heat loss from production tubing contributes to the formation of gas hydrates and causes the deposition of paraffin and asphaltene materials. Traditionally, controlling annular heat loss has been achieved with the injection of steam, the application of silicate foam, the pressurization of the annulus with inert gas, the use of gelled oil as an insulating packer fluid, and the use of vacuum insulated tubing (VIT). Each of these applications, however, has drawbacks because of either its working mechanism or the higher cost associated with the technology.To secure the insulation of the wellbore and to reduce heat transfer from the production tubing to the surrounding areas, various aqueous insulating fluid systems with superior thermal properties have been developed in recent years. Field applications of these fluids have demonstrated significant reduction in heat loss by reducing conduction and minimizing convection. These thermal insulating fluids have been implemented with great success in more than 75 deepwater riser and packer applications in the Gulf of Mexico (GOM) over the last several years. Case histories have demonstrated that installation of these water-based insulating fluids is an effective alternative to conventional insulation options and is becoming the preferred insulation method in many deepwater projects. This paper will highlight the evolution of different insulating fluid systems and the field experience with each system. Proper testing methods relevant to oilfield flow assurance will be discussed and testing results for these fluids will be detailed. Field cases in the GOM will be summarized, and the effectiveness of these fluid systems will be demonstrated.

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Section: History Of Thermal Insulation In the Oil Fieldsmentioning

confidence: 99%

“…One major mechanism for heat transfer in the wellbore is free convection Ashford et al 1990;Yousif and Young 1992). In certain conditions, convective heat loss could be more significant than molecular conduction, even for very lowconductivity materials such as mineral oil and diesel.…”

Section: Development Of Thermal-insulating Fluidsmentioning

confidence: 99%

New Trend in Oilfield Flow-Assurance Management: A Review of Thermal Insulating Fluids

Wang¹,

Qu²,

Javora³

et al. 2009

SPE Production &Amp; Operations

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“…In this instance, the heat loss from non-viscosified oil was associated with significant convection within the annulus 7,8 . However, thixotropic oil-based fluids that have a relative thermal conductivity about 13 percent that of water have been reported [9][10][11][12] . While these fluids can be weighted to higher densities, they potentially suffer from solids settling, emulsion destabilization, incompatibility with elastomer elements, and future environmental restrictions.…”

Section: Introductionmentioning

confidence: 99%

Water-Based Insulating Fluids for Deep-Water Riser Applications

Javora¹,

Wang²,

Stevens³

et al. 2004

SPE Asia Pacific Oil and Gas Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractUncontrolled heat transfer from production tubing to outer annuli, especially in deep-water riser sections, can cause the deposition of sludge, paraffin and asphaltene materials and contribute to the formation of gas hydrates. It also can limit the shut-in time if there is a need to shut down the well for remedial operations. Generally, deep-water risers can be insulated externally, or alternatively, insulated by placing nitrogen gas into the riser annulus. In recent years, a new water-based thermal insulating fluid system with superior thermal properties has been developed and used in field applications. This new system provides an ideal rheological profile to significantly reduce fluid convection caused by temperature differential and to facilitate fluid placement into the riser annulus. This system has been successfully used as an alternative to the current insulation method in deep-water risers in the Gulf of Mexico.Laboratory-scale equipment and a full-scale test well were constructed to evaluate the thermal insulation properties of fluids. This paper will detail both testing procedures and methods. Steady-state heat transfer and cool down test results on the new insulation fluid will be reviewed for both set-ups. The results will be discussed along with the results from similar tests on conventional brine based packer fluid, current insulation fluids, as well as nitrogen (air) and argon. The fullscale test data will be discussed in relation to modeling wellbore heat transfer. Field cases in GOM are also summarized to demonstrate the effectiveness of this fluid system.

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“…A number of approaches have been utilized to remediate the effects of wax deposition (Tuttle 1983;Ashford et al 1990), including hot oiling, wireline cutting and chemical treatments to prevent formation of wax deposits. In higher latitudes and beneath the sea, insulation may be necessary to prevent deposits forming in the well and transfer pipelines (Ashford et al 1990).…”

mentioning

confidence: 99%

“…In higher latitudes and beneath the sea, insulation may be necessary to prevent deposits forming in the well and transfer pipelines (Ashford et al 1990). However, the application of such techniques clearly results in additional production costs, the actual amounts being linked to the wax content of the petroleum (Tuttle 1983).…”

mentioning

confidence: 99%

Characterization of high molecular weight hydrocarbons (>C ₄₀ ) in oils and reservoir rocks

Philp

Bishop

Rı́o

et al. 1995

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The presence of high molecular weight hydrocarbons in crude oils has been known for some time, particularly in view of their ability to precipitate and form barriers and blockages in pipelines. Recent advances in analytical technology have led to the development of capillary columns for gas chromatography capable of withstanding high temperatures (350 to 450°C), which allow the characterization of hydrocarbons with carbon numbers as great as C100 and above. Consequently, the individual high molecular weight hydrocarbon compounds in oils and waxes can now be identified. In the present paper, results are presented from high temperature gas chromatographic analyses of naturally occurring waxes. These clearly show the presence of significant concentrations of hydrocarbons with carbon numbers in excess of C40 in many of these samples. In order to assist in the quantification of these high molecular weight hydrocarbons, we have also assessed the potential of thermal microdistillation coupled with a field ionization detector, to obtain more accurate molecular weight distributions in wax samples. This is based on the concept that high temperature gas chromatography has an upper carbon number limit in the range C100 to C120. Thermal distillation may provide the ability to exceed that limit and determine the presence of compounds above C120. More detailed characterization of the wax fractions on a molecular level has the potential to provide clues as to the composition and origin of the residual components left in a petroleum reservoir at the end of its production history. A better understanding of the nature of this material will lead to improved secondary and tertiary recovery mechanisms, and other enhanced oil recovery procedures.

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Annular Packer Fluids for Paraffin Control: Model Study and Successful Field Application

Cited by 21 publications

References 1 publication

New Trend in Oilfield Flow-Assurance Management: A Review of Thermal Insulating Fluids

New Trend in Oilfield Flow-Assurance Management: A Review of Thermal Insulating Fluids

Water-Based Insulating Fluids for Deep-Water Riser Applications

Characterization of high molecular weight hydrocarbons (>C ₄₀ ) in oils and reservoir rocks

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Annular Packer Fluids for Paraffin Control: Model Study and Successful Field Application

Cited by 21 publications

References 1 publication

New Trend in Oilfield Flow-Assurance Management: A Review of Thermal Insulating Fluids

New Trend in Oilfield Flow-Assurance Management: A Review of Thermal Insulating Fluids

Water-Based Insulating Fluids for Deep-Water Riser Applications

Characterization of high molecular weight hydrocarbons (>C 40 ) in oils and reservoir rocks

Contact Info

Product

Resources

About

Characterization of high molecular weight hydrocarbons (>C ₄₀ ) in oils and reservoir rocks