Calculated Temperature Behavior of Hot-Water Injection Wells

10.2118/95-pa ◽  
1962 ◽  
Vol 14 (04) ◽  
pp. 436-440 ◽  
Author(s):  
D.P. Squier ◽  
D.D. Smith ◽  
E.L. Dougherty
Keyword(s):  
Water Injection ◽  
Hot Water ◽  
Temperature Behavior ◽  
Injection Wells ◽  
Calculated Temperature

An Improved Simulation for Interpreting Temperature Logs in Water Injection Wells

1982 ◽  
Vol 22 (05) ◽  
pp. 709-718 ◽  
Author(s):  
John Fagley ◽  
H. Scott Fogler
Keyword(s):  
Heat Transfer ◽  
Digital Computer ◽  
Water Injection ◽  
Steam Injection ◽  
Hot Water ◽  
Injection Wells ◽  
Short Period ◽  
Injection Zone ◽  
Wellbore Temperature ◽  
Laplace Transformations

Abstract An improved simulation for temperature logs (TL's) in water injection wells is described. Improvements based on the reduction of assumptions used by previous investigators are demonstrated by comparison of field data and simulator results showing excellent agreement of TL profiles over the entire well depth. Initial work with the simulator has demonstrated the need for different operational procedures for definite TL surveys in mature wells (those having received significant long-term injection) as compared with young wells. The utility of short-period hot water (SPHW) injection just preceding shut-in as an injection profile amplifying scheme has been investigated in depth through the TL simulator. Finally, sensitivity studies have been run to identify the most important TL parameters and to develop guidelines for improved profiling. Introduction Injection of water into wells is done for three basic reasons: to maintain field pressure, for waterflooding, or to dispose of unwanted brine. For at least two of these it is desirable to know an injection profile. The TL is one way of defining injection profiles and is particularly useful in wells with outside-of-casing vertical flow.As fluid flows down the wellbore, the rock surrounding the wellbore (which is initially at the prevailing geothermal temperature) is heated or cooled by the injection water, depending on its temperature and the rate of heat transfer in the well. This effect is most pronounced in an injection zone where the fluid enters the rock formation, flowing radially outward, and where heat transfer occurs by both convection arid conduction. Except for hot-water and steam injection, the near-wellbore portion of the flooded zone normally will be cooled. Once the well is shut in and fluid flow is halted, the temperature of the well and the surrounding formation starts to return to the original geothermal temperature. The regions above and below the injection zone trend toward the geothermal temperature more rapidly than in the injection zone because of the greater heat transfer in the latter. Thus, by measurement of the wellbore temperature as a function of depth the location of the injection zone can be determined as the region where temperature anomalies occur.The interpretation of TL's to determine injection flow profiles has been attempted previously, both qualitatively and quantitatively. In early studies, quantitative analysis was made by use of Laplace transformations and Bessel function solutions. With the advent of the digital computer, more rigorous analysis can be made with numerical methods to treat heat transfer terms, which had to be removed by simplifying assumptions in the earlier studies.In this paper, we present an improved injection-well temperature simulator of the digital computer variety. This simulator offers an advantage over previous simulators in that wellbore-water heat transfer is modeled both before and after shut-in of the well. This capability allowed us to investigate possible solutions to the problem of lost profile definition in mature injection wells. We have found hot-water injection, for a short period before shut-in, to be a potentially important tool for defining injection fluid profiles in mature wells. SPEJ P. 709^

A New Method of Fall-Off Test in Water Injection Well in Tahe Oilfield

2013 ◽  
Vol 807-809 ◽  
pp. 2508-2513
Author(s):  
Qiang Wang ◽  
Wan Long Huang ◽  
Hai Min Xu
Keyword(s):  
Water Injection ◽  
Injection Well ◽  
Well Test ◽  
Well Bore ◽  
Residual Oil ◽  
Injection Wells ◽  
Oil Saturation ◽  
Tahe Oilfield ◽  
Fitting Method ◽  
Front Radius

In pressure drop well test of the clasolite water injection well of Tahe oilfield, through nonlinear automatic fitting method in the multi-complex reservoir mode for water injection wells, we got layer permeability, skin factor, well bore storage coefficient and flood front radius, and then we calculated the residual oil saturation distribution. Through the examples of the four wells of Tahe oilfield analyzed by our software, we found that the method is one of the most powerful analysis tools.

Development of an Optimized Formulation for Cleaning Water Injection Wells Drilled With Oil Based Systems

2007 ◽  
Author(s):  
Christine S.H. Dalmazzone ◽  
Amandine Le Follotec ◽  
Annie Audibert-Hayet ◽  
Allan Jeffery Twynam ◽  
Hugues M. Poitrenaud
Keyword(s):  
Water Injection ◽  
Injection Wells

scholarly journals A Numerical Method for Computing Recovery of Oil By Hot Water Injection in a Radial System

1965 ◽  
Vol 5 (02) ◽  
pp. 131-140 ◽  
Author(s):  
K.P. Fournier
Keyword(s):  
Thermal Expansion ◽  
Oil Recovery ◽  
Viscosity Ratio ◽  
Water Injection ◽  
Injection Rate ◽  
Heat Losses ◽  
Hot Water ◽  
Radial System ◽  
System Equation ◽  
Finite Difference Equations

Abstract This report describes work on the problem of predicting oil recovery from a reservoir into which water is injected at a temperature higher than the reservoir temperature, taking into account effects of viscosity-ratio reduction, heat loss and thermal expansion. It includes the derivation of the equations involved, the finite difference equations used to solve the partial differential equation which models the system, and the results obtained using the IBM 1620 and 7090–1401 computers. Figures and tables show present results of this study of recovery as a function of reservoir thickness and injection rate. For a possible reservoir hot water flood in which 1,000 BWPD at 250F are injected, an additional 5 per cent recovery of oil in place in a swept 1,000-ft-radius reservoir is predicted after injection of one pore volume of water. INTRODUCTION The problem of predicting oil recovery from the injection of hot water has been discussed by several researchers.1–6,19 In no case has the problem of predicting heat losses been rigorously incorporated into the recovery and displacement calculation problem. Willman et al. describe an approximate method of such treatment.1 The calculation of heat losses in a reservoir and the corresponding temperature distribution while injecting a hot fluid has been attempted by several authors.7,8 In this report a method is presented to numerically predict the oil displacement by hot water in a radial system, taking into account the heat losses to adjacent strata, changes in viscosity ratio with temperature and the thermal-expansion effect for both oil and water. DERIVATION OF BASIC EQUATIONS We start with the familiar Buckley-Leverett9 equation for a radial system:*Equation 1 This can be written in the formEquation 2 This is sometimes referred to as the Lagrangian form of the displacement equation.

SS - Gas Hydrate: Gas production from methane hydrate sediment layer by thermal stimulation with hot water injection

2010 ◽  
Author(s):  
Kyuro Sasaki ◽  
Shinzi Ono ◽  
Yuichi Sugai ◽  
Norio Tenma ◽  
Takao Ebinuma ◽  
...  
Keyword(s):  
Gas Hydrate ◽  
Methane Hydrate ◽  
Water Injection ◽  
Gas Production ◽  
Hot Water ◽  
Thermal Stimulation ◽  
Sediment Layer

Short Radius Horizontal and Multilateral Re-entry of Oil and Water Injection Wells

1998 ◽  
Author(s):  
I.A. Al-Ghamdi ◽  
A.A. Al-Hendi ◽  
O.J. Esmail
Keyword(s):  
Water Injection ◽  
Injection Wells
Sign in / Sign up

Export Citation Format

Share Document