Cementing Temperatures for Deep-Well Production Liners

Wooley, G.R.; Giussani, Alberto; Galate, J.W.; Wedelich, H.

doi:10.2118/13046-ms

Cited by 16 publications

(3 citation statements)

References 3 publications

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“…7 Under normal cementing conditions for vertical wells, API tables and calculations have been used successfully for many years. However, for HPHT wells, the high temperatures cause the slurries to be sensitive to temperature and, therefore, the accuracy of the predicted cementing temperature is more critical.…”

Section: Temperaturementioning

confidence: 99%

Central Graben Extreme Offshore High-Pressure/High-Temperature Cementing Case Study

John

Brangetto²,

Gray

2000

All Days

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This paper presents the cementing case histories of six wells in two offshore high-pressure, high-temperature (HPHT) fields in the Central Graben area of the North Sea. Well depths averaged 6000 m true vertical depth (TVD), temperatures were greater than 200 o C, the fracture/pore-pressure margin was small, and the bottomhole pressure exceeded 1,100 bar. The well deviation varied from near vertical to a maximum of 35°. These downhole conditions are the most extreme yet experienced in a field development in the North Sea.Because of the extreme HPHT conditions, all aspects of cementing operations had to be carefully evaluated. In addition, new and enhanced equipment, processes, and materials had to be developed. Even though the potential for gas influx of the cement was high, the cement slurry formulation and placement techniques for resisting gas migration were successfully designed through the use of materials with a low environmental impact. Because the formations were weak and unconsolidated, a special cement blend was used at the top of the well. The mixing equipment was modified to withstand the high-density fluids required for the liner section.For job success, both a well-defined top-of-cement (TOC) and good casing support had to be obtained without exceeding the allowable equivalent circulating density (ECD) limit. Therefore, effective mud displacement, correct slurry placement, and precise rheology measurement were required.No remedial HPHT cementing operations were necessary during these operations, which was an important objective. Remedial operations could have posed extreme risks and high associated costs. This paper describes how the cementing process was optimized for HPHT field development, thereby minimizing risk and costs. Considerable emphasis is placed on the production liner cement job, because it was the most critical string on the well. Improvements to equipment, slurry testing, placement, and bond logging procedures are also described.

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Section: Temperaturementioning

confidence: 99%

Central Graben Extreme Offshore High-Pressure/High-Temperature Cementing Case Study

John

Brangetto²,

Gray

2000

All Days

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“…Computer models specific to well cementing have been available for more than 20 years and have been shown to have reasonable accuracy in conventional wells 4 , deviated wells 5 , HTHP wells 6 , and deepwater wells 7,8,9 . Until recently, output from these simulators had been considered adequate for most cementing applications.…”

Section: Introductionmentioning

confidence: 99%

Mathematical Temperature Simulators for Drilling Deepwater HT/HP Wells: Comparisons, Applications, and Limitations

Stiles

Trigg

2007

Proceedings of SPE/IADC Drilling Conference

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TX 75083-3836 U.S.A., fax 1.972.952.9435. AbstractThe widespread application and acceptance of mathematical simulators to model wellbore temperatures during drilling operations has grown in recent years. The increasing complexity of today's wells makes these physics-based tools invaluable for such tasks as designing successful cementing operations, selecting elastomers for blowout preventers, and selecting proper downhole tools. Limited previous work has validated some of these models against measured well temperatures but no comparison among the results, applications, and limitations of the various models has been published.Part one of this paper presents a comparison of cementing temperature results from three models widely used by the industry today. The input parameters for this study were based upon a typical deepwater well in West Africa. While each of the simulators utilizes similar heat transfer models, the output from the models was found to differ significantly under certain well conditions. In some of the cases studied, differences among the simulated cementing temperatures were significant enough to warrant performance of risk analysis and implementation of risk mitigation measures.Part two of this paper presents the circulating temperature model and temperature surveillance program utilized to drill and test a deepwater high temperature high pressure (HTHP) well. The predictions from the model were used to evaluate design considerations such as the selection of blowout preventer (BOP) elastomers and qualification of downhole drilling and testing tools. The model aided in completion fluid selection to optimize hydrate prevention and influence flowing wellhead and surface temperatures. A comparison of modeled parameters and measured field data is included.In addition to the model results, the functionalities of each of the temperature simulators and how those functionalities may influence the results are discussed. A discussion on the applicability and limitation of the models to the deepwater conditions studied is included as well as recommendations for managing and mitigating the associated risk.

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“…Many such models have appeared in the literature taking into account many variables that affect temperature. The complexity varies from correlation [7] and one-dimensional steadystate models [8] to two or three-dimensional transient simulators [9][10][11][12][13][14][15][16]. Some of them are unconvincing since the validations are based on incomplete sets of data inputs.…”

Section: Introductionmentioning

confidence: 99%

A Cementing Temperature Simulator yo Improve Field Practice

1993

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It has long been known that temperature during circulation and after cement placement is one ofthe most important parameters for the design of a slurry and the success of cement jobs. Since API co"elations do not take into account important parameters affecting the temperature evolution, simulators,which are sensitive to little known parameters, have been developed. This has made validation difficult or unconvincing, as there always exists a set of input parameters that can match observed temperature on a particular well. It has also significantly limited the widespread use of temperature simulators for field operations.In this paper we present a cementing temperature simulator which has been developed taking this inherent difficulty iilto account. The validation was performed by testing against 30 jobs from the API database, selected based on data completeness.With this simulator, temperature prediction has been considerably improved over the API method. The standard deviation, maximum overestimation and maximum underestimation have been reduced on the thirty API jobs.This model applies equally well to onshore and offshore,vertical and deviated wells, and takes into account other variables that affect temperatures while cementing.

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Cementing Temperatures for Deep-Well Production Liners

Cited by 16 publications

References 3 publications

Central Graben Extreme Offshore High-Pressure/High-Temperature Cementing Case Study

Central Graben Extreme Offshore High-Pressure/High-Temperature Cementing Case Study

Mathematical Temperature Simulators for Drilling Deepwater HT/HP Wells: Comparisons, Applications, and Limitations

A Cementing Temperature Simulator yo Improve Field Practice

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