Analysis of Wellbore Temperature Distribution and Influencing Factors During Drilling Horizontal Wells

2018 ◽  
Vol 140 (9) ◽  
Author(s):  
Zheng Zhang ◽  
Youming Xiong ◽  
Fang Guo
Keyword(s):  
Temperature Distribution ◽  
Significant Influence ◽  
Drilling Fluid ◽  
Geothermal Gradient ◽  
Transient Temperature ◽  
Inlet Temperature ◽  
Outlet Temperature ◽  
Horizontal Section ◽  
Geothermal Resources ◽  
Wellbore Temperature

Horizontal well drilling technology is widely used in the exploitation of petroleum and natural gas, shale gas, and geothermal resources. The temperature distribution of wellbore and surrounding formation has a significant influence on safe and fast drilling. This study aims to investigate the temperature distribution of horizontal wellbores during circulation by using transient temperature model. The transient temperature prediction model was established by the energy conservation law and solved by the relaxation iterative method. The validity of the model has been verified by the field data from the Tarim Oilfield. The calculation results showed that the highest temperature of the drilling fluid inside the drill string was at the bottomhole and the highest temperature of annulus drilling fluid was at some depth away from the bottomhole. Sensitivity analysis of various factors that affect the temperature distribution of annulus drilling fluid were carried out, including the circulation time, the flow rate, the density of drilling fluid, the inlet temperature, the vertical depth, the horizontal section length, and the geothermal gradient. It can be found that the vertical depth and the geothermal gradient have a significant influence on the bottomhole temperature, and inlet temperature plays a decisive influence on the outlet temperature. These findings can supply theoretical bases for the horizontal wellbore temperature distribution during drilling.

scholarly journals Prediction of Wellbore Temperatures During the Scientific Ultra-Deep Drilling Process

2015 ◽  
Vol 8 (1) ◽  
pp. 451-456 ◽  
Author(s):  
Fanhe Meng ◽  
Aiguo Yao ◽  
Shuwei Dong
Keyword(s):  
Drilling Fluid ◽  
Great Influence ◽  
Inlet Temperature ◽  
Drilling Process ◽  
Fluid Viscosity ◽  
Key Factors ◽  
Deep Drilling ◽  
Fluid Displacement ◽  
Temperature Distributions ◽  
Wellbore Temperature

In order to carry out a series of key basic researches, a scientific ultra-deep drilling plan is being undertaken in China. Wellbore temperature is one of the key factors during the drilling process. In this paper, we established a twodimensional transient numerical model to predict the ultra-deep wellbore temperature distributions during circulation and shut-in stages. The simulation results indicate that the cooling effect of drilling fluid circulation is very obvious, especially during the inception phase. Drilling fluid viscosity has great influence on the temperature distributions during circulation stage: the lower the viscosity, the higher the bottomhole temperature. While drilling fluid displacement and inlet temperature have a little effect on the bottomhole temperature. During the shut-in stage, the wellbore temperature recovery is a slow process.

scholarly journals Validation of analytical model and identification of salt effect on wellbore temperature in underbalanced drilling

2021 ◽  
Author(s):  
Olatunji Olayiwola ◽  
Vu Nguyen ◽  
Opeyemi Bello ◽  
Ebuka Osunwoke ◽  
Boyun Guo ◽  
...  
Keyword(s):  
Temperature Distribution ◽  
Quantitative Methods ◽  
Drilling Fluid ◽  
Recovery Process ◽  
Accurate Estimate ◽  
Fluid Composition ◽  
Fluid Temperature ◽  
Wellbore Temperature ◽  
Drilling Operations ◽  
Saline Formation

AbstractUnderstanding the behavior of the borehole temperature recovery process, which influences drilling operations, requires an adequate estimation of fluid temperature. The presence of salt in a saline formation changes the composition of the annular fluid and has a significant impact on the fluid temperature distribution during drilling operations. As a result, while drilling a saline formation, it is vital to examine the key parameter that determines an accurate estimate of fluid temperature. Using python software and statistical quantitative methods, this study proposes a simplified user-friendly computational system that analyzes the drilling fluid systems performance evaluation and selection optimization.The fluid temperature distribution of X Field in China was analyzed using Shan mathematical model as a base model. When compared to MWD data from the field, the model predicted the temperature distribution of the field with less than 10% error. An adjustment factor was introduced to the base model to accommodate for changes in annular fluid composition while drilling a saline formation. The findings show that salt concentration has an impact on fluid temperature distribution during drilling. The fluid temperature at the wellbore condition changes by at least 7% with both high and low adjustment factors. Because the salt in the formation inflow dissolves in the drilling fluid near the annulus, the rheology of the fluid combination changes.

Influence of the location of drilling fluid loss on wellbore temperature distribution during drilling

Energy ◽  
2021 ◽  
pp. 123031
Author(s):  
Zheng Zhang ◽  
Yongqi Wei ◽  
Youming Xiong ◽  
Geng Peng ◽  
Guorong Wang ◽  
...  
Keyword(s):  
Temperature Distribution ◽  
Drilling Fluid ◽  
Fluid Loss ◽  
Wellbore Temperature

Estimation of Undisturbed Geothermal Gradient in Wells From Measured Drilling Data: A Numerical Approach

2017 ◽  
Author(s):  
Lucas Cantinelli Sevillano ◽  
Jesus De Andrade ◽  
Sigbjørn Sangesland
Keyword(s):  
Heat Transfer ◽  
Thermal Properties ◽  
Temperature Distribution ◽  
Oil And Gas ◽  
Drilling Fluid ◽  
Geothermal Gradient ◽  
Computer Code ◽  
Numerical Approach ◽  
Rock Properties ◽  
Drilling Fluids

The undisturbed geothermal gradient is a key thermal boundary that drives heat transfer processes occurring in oil and gas wells throughout their lifetime. However, the temperature distribution with depth is somewhat uncertain, and this is often assumed to be a linear approximation from the mudline to the bottom of the well. During drilling, the circulating temperature may significantly affect the rheology of the drilling fluids and the cement setting processes. Therefore, erroneous estimates of the wellbore temperature may affect the overall performance of the drilling phase and subsequent well operations. Further, it is important to know the accurate temperature distribution within the formation for assessment of the petroleum prospectivity through source rock maturation and reservoir quality. This paper presents a numerical methodology to estimate the undisturbed geothermal gradient while drilling in offshore wells. This methodology may also be applied to onshore wells by simplification. The new approach is based on an in-house axisymmetric wellbore transient thermal model, in which the equations are solved using the finite difference method. The model computes the heat transfer between the well and riser system with the surroundings. However, other computational codes may also be used following the framework presented in this study. The computer code should provide a detailed representation of the geometry of the wellbore, the physical properties of the drilling fluid and formation, the suitable thermal boundary conditions and temporal discretization. The temperatures of the fluid at the inlet of the drillstring and at the bottom hole assembly (BHA), in the annulus A, are used as input to the numerical model that iteratively adjusts the undisturbed geothermal gradient, which generated the temperature recordings while drilling. The paper comprises cases studies of hypothetical wells drilled in relevant offshore areas in the world, each with their distinctive and variable geothermal gradient, defined by the different rock formations encountered. Uncertainties regarding the thermal properties of the rock were also considered to ascertain the robustness of the code. The water depth of the drilling site was also observed to impact the convergence of the algorithm. The results obtained by the numerical approach are in good agreement with the expected values of the undisturbed formation temperatures. The novelty of the numerical framework is the ability to provide reliable and satisfactory estimates of the undisturbed geothermal gradient for wellbores with any configuration, lithology and rock properties. These estimates are based on temperature measurements of the circulating drilling fluid at the BHA and account for uncertainty in rock thermal properties; in reasonable time using standard engineering computers.

Interpretation and Analysis of Transient-Sandface- and Wellbore-Temperature Data

SPE Journal ◽  
2017 ◽  
Vol 22 (04) ◽  
pp. 1156-1177 ◽  
Author(s):  
M.. Onur ◽  
G.. Ulker ◽  
S.. Kocak ◽  
I. M. Gok
Keyword(s):  
Geothermal Gradient ◽  
General Purpose ◽  
Temperature Data ◽  
Heat Losses ◽  
Transient Temperature ◽  
Late Time ◽  
Wellbore Temperature ◽  
Conservation Of Momentum ◽  
Skin Zone ◽  
Straight Lines

Summary This paper presents new analytical and semianalytical solutions derived from a coupled transient-wellbore/reservoir thermal model to investigate the information content of transient-temperature measurement made within the vertical wellbore across from the producing horizon or at a gauge depth above it during drawdown and buildup tests. The solutions consider flow of a slightly compressible, single-phase fluid in a homogeneous infinite-acting reservoir system with skin modeled as a composite zone adjacent to the wellbore and account for the Joule-Thomson (J-T) heating/cooling, adiabatic-fluid expansion, conduction and convection effects both in the wellbore and reservoir. They are developed depending on the assumption that the effects of temperature changes on wellbore and reservoir-pressure-transient data can be neglected so that the mass-, momentum-, and energy-balance equations in the wellbore and reservoir can be decoupled. The semianalytical solution for predicting sandface temperatures is verified by use of a general-purpose thermal simulator. Wellbore temperatures at a certain gauge depth are evaluated through the analytical steady-state and transient-wellbore-temperature equations coupled with a semianalytical reservoir-temperature model accounting for conservation of momentum in the wellbore. Results show that drawdown- and buildup-sandface-temperature data may exhibit two semilog straight lines: one at early times reflecting the effects of adiabatic-fluid expansion in the skin zone near the wellbore, and the other, the late-time semilog straight line, reflecting the J-T effects and exhibiting the nonskin-zone properties. However, the wellbore-temperature measurements made at locations above the producing horizon may not exhibit these semilog straight lines because they are strongly dependent upon distance above the producing horizon, geothermal gradient, and radial-heat losses from the wellbore fluid to the formation on the way to gauge. It is found that the skin-zone properties are very difficult to be estimated from drawdown- and buildup-wellbore temperatures unless the gauge location is not far from the producing zone. Specifically, we found that buildup-wellbore temperature is mostly dominated by wellbore-heat losses compared with drawdown-wellbore-temperature data, and hence may not be useful to estimate the formation properties, including skin-zone properties.

Full Transient Features of Heat Transfer and Sensitivities on Deep Water Wells

2012 ◽  
Vol 524-527 ◽  
pp. 1423-1428
Author(s):  
Xun Cheng Song ◽  
Xiao Long Xu ◽  
Sha Sha Hu ◽  
Zhi Chuan Guan
Keyword(s):  
Heat Transfer ◽  
Temperature Profile ◽  
Water Depth ◽  
Deep Water ◽  
Sea Water ◽  
Drilling Fluid ◽  
Inlet Temperature ◽  
Bottom Hole ◽  
Sea Bed ◽  
Wellbore Temperature

Wellbore temperature is significant to well program and safety drilling for deep water drilling operations. On the basis of transient heat transfer mechanisms involved in deep water drilling among wellbore and formation and sea water, wellbore temperature profile, especially near sea bed and sensitivities to drilling fluid circulating duration, inlet temperature, water depth, water temperature, riser insulation and drilling fluid specific heat capacity have been analyzed via this model. Analysis show that deep-water wellbore temperature is much lower than a land well, the temperatures above sea bed normally ranges 10-30°C, and decreases with increased circulating duration; temperature at both outlet and bottom hole decreases drastically with increased water depth, and heat generation must be considered into estimating wellbore temperature profile especially one at bottom hole.

scholarly journals Wellbore Temperature and Pressure Field in Deep-water Drilling and the Applications in Prediction of Hydrate Formation Region

2021 ◽  
Vol 9 ◽  
Author(s):  
Wantong Sun ◽  
Na Wei ◽  
Jinzhou Zhao ◽  
Shouwei Zhou ◽  
Liehui Zhang ◽  
...  
Keyword(s):  
Deep Water ◽  
Drilling Fluid ◽  
Hydrate Formation ◽  
Prediction Method ◽  
Geothermal Gradient ◽  
Formation Region ◽  
Fully Implicit ◽  
Wellbore Pressure ◽  
Wellbore Temperature ◽  
Influence Degree

In the process of deep-water drilling, gas hydrate is easily formed in wellbores due to the low temperature and high pressure environment. In this study, a new, systematic, and accurate prediction method of temperature, pressure, and hydrate formation region in wellbores is developed. The mathematical models of wellbore pressure and transient heat transfer are established, the numerical solution method based on fully implicit finite difference method is developed, and the accuracy is verified by comparing with the field measured data. Combined with the hydrate phase equilibrium model, the hydrate formation region in wellbore is predicted, and the sensitivity effects of nine factors on wellbore temperature, pressure, and hydrate formation region are analyzed. Finally, the influence regularities and degree of each parameter are obtained. The increases of circulation time, geothermal gradient, displacement of drilling fluid, and injection temperature will inhibit the formation of hydrate in wellbores, and the influence degree increases in turn; the increases of wellhead backpressure and seawater depth will promote the formation of hydrate in wellbores, and the influence degree increases in turn. The changes of drilling fluid density, well depth, and hole deviation angle have little effect on the formation of hydrate in wellbores.

scholarly journals LTNE Approach and Simulation for Anode-Supported SOFCs

2009 ◽  
Author(s):  
Martin Andersson ◽  
Jinliang Yuan ◽  
Bengt Sunde´n ◽  
Wei Guo Wang
Keyword(s):  
Fuel Cells ◽  
Fuel Cell ◽  
Temperature Distribution ◽  
Solid Phase ◽  
Flow Direction ◽  
Major Influence ◽  
Inlet Temperature ◽  
Outlet Temperature ◽  
Dominant Design ◽  
Phases Of Development

Fuel cells are promising for future energy systems, since they are energy efficient and, when hydrogen is used as fuel, there are no emissions of greenhouse gases. Fuel cells have during recent years various improvements, however the technology is still in the early phases of development, this can be noted by the lack of dominant design both for singe fuel cells, stacks and for entire fuel cell systems. In this study a CFD approach (COMSOL Multiphysics) is employed to investigate the effect on temperature distribution from inlet temperature, oxygen surplus, ionic conductivity and current density for an anode-supported intermediate temperature solid oxide fuel cell (IT-SOFC). The developed model is based on the governing equations of heat-, mass- and momentum transport. A local temperature non equilibrium (LTNE) approach is introduced to calculate the temperature distribution in the gas- and solid phase separately. The results show that the temperature increasing along the flow direction is controlled by the degree of surplus air. It is also found that the ohmic polarization in the electrolyte and the activation polarization in the anode and cathode have major influence on the performance. If a count flow approach is employed the inlet temperature for the fuel stream should be close to the outlet temperature for the air flow to avoid a too high temperature gradient.

scholarly journals Heat Transfer Behaviors in Horizontal Wells Considering the Effects of Drill Pipe Rotation, and Hydraulic and Mechanical Frictions during Drilling Procedures

Energies ◽  
2018 ◽  
Vol 11 (9) ◽  
pp. 2414 ◽  
Author(s):  
Xin Chang ◽  
Jun Zhou ◽  
Yintong Guo ◽  
Shiming He ◽  
Lei Wang ◽  
...  
Keyword(s):  
Heat Transfer ◽  
Oil And Gas ◽  
Drilling Fluid ◽  
Drill Pipe ◽  
Horizontal Wells ◽  
Fluid Temperature ◽  
Horizontal Section ◽  
Pressure Drops ◽  
Pressure Losses ◽  
Wellbore Temperature

Horizontal wells are increasingly being utilized in the exploration and development of oil and gas resources. However, the high temperature that occurs during drilling processes leads to a number of problems, such as the deterioration of drilling fluid properties and borehole instability. Therefore, the insight into heat transfer behaviors in horizontal wells is certainly advantageous. This study presents an integrated numerical model for predicting the temperature distribution during horizontal wells drilling considering the effects of drill pipe rotations, and hydraulic (i.e., circulating pressure losses) and mechanical frictions. A full implicit finite difference method was applied to solve this model. The results revealed that the mechanical frictions affect more on wellbore temperature variation than the effects of heat transfer intensification and circulating pressure losses; Moreover, the drilling fluid temperature was found higher than the stratum temperature at horizontal section, the temperature difference at the bottom hole reached up to 16 °C if pressure drops, heat transfer strengthened by rotations and mechanical frictions were all taken into account. This research could be utilized as a theoretical reference for predicting temperature distributions and estimating risks in horizontal wells drilling.

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