US20110155464A1 - Method for the identification of the formation fluid invasion moment - Google Patents
Method for the identification of the formation fluid invasion moment Download PDFInfo
- Publication number
- US20110155464A1 US20110155464A1 US12/981,058 US98105810A US2011155464A1 US 20110155464 A1 US20110155464 A1 US 20110155464A1 US 98105810 A US98105810 A US 98105810A US 2011155464 A1 US2011155464 A1 US 2011155464A1
- Authority
- US
- United States
- Prior art keywords
- formation fluid
- temperature
- identification
- moment
- fluids
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
- 239000012530 fluid Substances 0.000 title claims abstract description 58
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 31
- 230000009545 invasion Effects 0.000 title claims abstract description 22
- 238000000034 method Methods 0.000 title claims abstract description 19
- 239000000523 sample Substances 0.000 claims abstract description 23
- 238000005086 pumping Methods 0.000 claims abstract description 5
- 238000005553 drilling Methods 0.000 claims description 10
- 239000000706 filtrate Substances 0.000 claims description 7
- 239000000203 mixture Substances 0.000 abstract description 11
- 238000005070 sampling Methods 0.000 abstract description 9
- -1 hydraulic system Substances 0.000 abstract 1
- 230000003287 optical effect Effects 0.000 description 5
- 239000000243 solution Substances 0.000 description 5
- 238000011109 contamination Methods 0.000 description 3
- 238000002347 injection Methods 0.000 description 2
- 239000007924 injection Substances 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- 238000009529 body temperature measurement Methods 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 238000000746 purification Methods 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
- E21B49/10—Obtaining fluid samples or testing fluids, in boreholes or wells using side-wall fluid samplers or testers
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/008—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by injection test; by analysing pressure variations in an injection or production test, e.g. for estimating the skin factor
Definitions
- the invention is related to a method of identifying a formation fluid invasion and may be used, for example, to determine the filtrate injection depth, formation fluid mobility, viscosity contrast between the formation fluid and filtrate, formation anisotropy value etc.
- the drilling mud is injected into the formation and during formation fluid sampling the sample is contaminated.
- the hydrocarbon sample is contaminated with the oil-based drilling mud.
- the water sample is contaminated with the water-based drilling mud.
- Identification of the formation fluid properties using a contaminated sample results in substantial errors. Therefore, to obtain a pure sample a long pumpout process is required during which the sample is cleaned.
- the formation fluid invasion time identification is very important, for example, for the fluid injection depth identification.
- the existing methods of the invasion identification are based on measuring the pumped-out fluids' optical density.
- the disadvantages of the known methods for the formation fluid invasion time identification are measurement errors.
- the closest prior art is the method for the identification of the formation fluid invasion consisting in the sinking of the apparatus for the fluid mixture sampling (containing drilling mud filtrate and formation fluid) into the uncased wellbore, the apparatus consists of the body, standard probe and a hydraulic system described in [[Mullins, O. C., Schroer, J.: Real-time identification of filtrate contamination during openhole wireline sampling by optical spectroscope. Paper SPE 63071 presented at the 2000 SPE Annual Technical Conference and Exhibition, Dallas, Tex., 1-4 Oct. 2000].
- the disadvantage of the method above is obtaining an approximate solution for the identification of the formation fluid invasion time.
- the proposed method for the identification of the formation fluid invasion time does not require the use of the approximate solution which enables improvement of the formation fluid invasion moment identification.
- the invention is aimed at the facilitation of solving the problem of creating a simple and accurate method of the formation fluid invasion moment identification.
- This invention offers a new method of the formation fluid invasion moment identification by temperature measurements providing a more accurate identification of the formation fluid invasion moment.
- the method of the formation fluid invasion moment identification comprises the following steps.
- a sampling apparatus for the formation fluid mixture (consisting of the drilling mud filtrate and formation fluid) is sunk into the uncased wellbore; the apparatus consists of a body, standard probe, hydraulic system, chamber for the sample storage and pumping module; the fluid mixture is pumped out simultaneously with the measurement of the temperature of the fluids being pumped out, the temperature is measured using at least one temperature transducer positioned at the sampling apparatus hydraulic system inlet, by the values obtained the graph of the fluid temperature derivative as function of time is built up, the graph is used to identify the formation fluid invasion moment.
- FIG. 1 shows the apparatus for the fluid mixture sampling
- FIG. 2 shows the change of the pumped-out fluids' contamination as function of time and average integral temperature time derivative
- FIG. 3 shows the change of the sample integral average temperature vs. The pump-out time
- the apparatus for the fluid mixture sampling consists of a body 2 , at least one temperature transducer 1 , a standard probe 3 , a pumping module 6 , interconnected by a hydraulic system 4 by which, via the standard probe 3 the fluids collected are routed to a sample storage chamber 5 .
- the standard probe may be, in particular, a double-packer one.
- At least one temperature transducer 1 is mounted at the inlet of the collected fluid sample to the hydraulic system 4 .
- the method of the formation fluid invasion moment identification is based on the record of the surge of the integral average temperature of the pumped-out fluids.
- the method is applicable for both vertical and horizontal wellbores.
- the temperature profile of the bottom-hole area changes as follows: during the drilling mud circulation the bottom-hole area is cooled down and then during the wellbore shutdown the bottom-hole area temperature is recovered.
- the temperature of the pumped-out fluids is measured using at least one temperature transducer mounted at the hydraulic system inlet for taking the fluid mixture sample.
- the fluid mixture consisting of the drilling mud filtrate and formation fluid is pumped out and simultaneously with the pumping-out the temperature of pumped-out fluids is measured using at least one temperature transducer.
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- Analytical Chemistry (AREA)
- Sampling And Sample Adjustment (AREA)
Abstract
The method of the formation fluid invasion moment identification consists in the sinking of an apparatus for the sampling of the fluid mixture into the uncased wellbore; the apparatus consists of the body, standard probe, hydraulic system, sample storage chamber and pumping module. Then the fluid mixture is pumped out and simultaneously the temperature of the fluids being pumped out is measured using at least one temperature transducer positioned in the sampling apparatus hydraulic system. Based on the values obtained the graph of the derivative temperature of the pumped out fluids as function of time is built up and the formation fluid invasion moment is identified.
Description
- The invention is related to a method of identifying a formation fluid invasion and may be used, for example, to determine the filtrate injection depth, formation fluid mobility, viscosity contrast between the formation fluid and filtrate, formation anisotropy value etc.
- During drilling with a positive differential pressure the drilling mud is injected into the formation and during formation fluid sampling the sample is contaminated. The hydrocarbon sample is contaminated with the oil-based drilling mud. The water sample is contaminated with the water-based drilling mud. Identification of the formation fluid properties using a contaminated sample results in substantial errors. Therefore, to obtain a pure sample a long pumpout process is required during which the sample is cleaned. During the pumpout the formation fluid invasion time identification is very important, for example, for the fluid injection depth identification. The existing methods of the invasion identification are based on measuring the pumped-out fluids' optical density. The disadvantages of the known methods for the formation fluid invasion time identification are measurement errors.
- The idea of the sample cleaning process optical monitoring is based on the Beer-Lambert Law stating that the optical density (OD) of the two fluids mixture is equal to the sum of their weighted optical densities with the molar concentrations in the mixture. Obviously, the solution to the equation with two unknown quantities is not the only one and therefore does not provide the identification of the contamination level during the sample purification. To eliminate the solution non-uniqueness an approximated asymptotic solution is introduced.
- The closest prior art is the method for the identification of the formation fluid invasion consisting in the sinking of the apparatus for the fluid mixture sampling (containing drilling mud filtrate and formation fluid) into the uncased wellbore, the apparatus consists of the body, standard probe and a hydraulic system described in [[Mullins, O. C., Schroer, J.: Real-time identification of filtrate contamination during openhole wireline sampling by optical spectroscope. Paper SPE 63071 presented at the 2000 SPE Annual Technical Conference and Exhibition, Dallas, Tex., 1-4 Oct. 2000]. The disadvantage of the method above is obtaining an approximate solution for the identification of the formation fluid invasion time.
- The proposed method for the identification of the formation fluid invasion time does not require the use of the approximate solution which enables improvement of the formation fluid invasion moment identification.
- The invention is aimed at the facilitation of solving the problem of creating a simple and accurate method of the formation fluid invasion moment identification.
- This invention offers a new method of the formation fluid invasion moment identification by temperature measurements providing a more accurate identification of the formation fluid invasion moment.
- The method of the formation fluid invasion moment identification comprises the following steps. A sampling apparatus for the formation fluid mixture (consisting of the drilling mud filtrate and formation fluid) is sunk into the uncased wellbore; the apparatus consists of a body, standard probe, hydraulic system, chamber for the sample storage and pumping module; the fluid mixture is pumped out simultaneously with the measurement of the temperature of the fluids being pumped out, the temperature is measured using at least one temperature transducer positioned at the sampling apparatus hydraulic system inlet, by the values obtained the graph of the fluid temperature derivative as function of time is built up, the graph is used to identify the formation fluid invasion moment.
-
FIG. 1 shows the apparatus for the fluid mixture sampling; -
FIG. 2 shows the change of the pumped-out fluids' contamination as function of time and average integral temperature time derivative; and -
FIG. 3 shows the change of the sample integral average temperature vs. The pump-out time; - The apparatus for the fluid mixture sampling consists of a
body 2, at least onetemperature transducer 1, astandard probe 3, apumping module 6, interconnected by ahydraulic system 4 by which, via thestandard probe 3 the fluids collected are routed to asample storage chamber 5. The standard probe may be, in particular, a double-packer one. At least onetemperature transducer 1 is mounted at the inlet of the collected fluid sample to thehydraulic system 4. - The method of the formation fluid invasion moment identification is based on the record of the surge of the integral average temperature of the pumped-out fluids. The method is applicable for both vertical and horizontal wellbores.
- During the wellbore drilling the temperature profile of the bottom-hole area changes as follows: during the drilling mud circulation the bottom-hole area is cooled down and then during the wellbore shutdown the bottom-hole area temperature is recovered. The temperature of the pumped-out fluids is measured using at least one temperature transducer mounted at the hydraulic system inlet for taking the fluid mixture sample. The fluid mixture consisting of the drilling mud filtrate and formation fluid is pumped out and simultaneously with the pumping-out the temperature of pumped-out fluids is measured using at least one temperature transducer. By the values obtained the graph of the derivative temperature of the pumped-out fluids as a function of time is built up and the formation fluid invasion moment is identified. As
FIG. 2 shows, at the moment of the formation fluid invasion the sign of the derivative average integral temperature is changed which corresponds to the occurrence of a small peak at the graph of the derivative temperature of the pumped-out fluids (FIG. 3 ). By this change record the moment of the formation fluid invasion is identified.
Claims (4)
1. A method for a formation fluid invasion identification comprising the steps of:
lowering a fluid mix sampler into an uncased borehole, fluid mix consisting of a drilling mud filtrate and a reservoir fluid, the sampler including an enclosure, a standard probe, a hydraulic system, a chamber for probes storage and a pumping module,
pumping off the fluid mix simultaneously with measuring temperature of the fluids being pumped off using at least one temperature transducer located in the hydraulic system of the sampler,
constructing a graph of the pumped off fluids temperature derivative as a function of the time based on the values obtained, and
determining the formation fluid invasion time.
2. The method of claim 1 wherein a borehole is vertical.
3. The method of claim 1 wherein a borehole is horizontal.
4. The method of claim 1 wherein a standard probe is a double-packer.
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
RU2009149591/03A RU2431035C2 (en) | 2009-12-31 | 2009-12-31 | Method for determining formation fluid invasion point |
RU2009149591 | 2009-12-31 |
Publications (1)
Publication Number | Publication Date |
---|---|
US20110155464A1 true US20110155464A1 (en) | 2011-06-30 |
Family
ID=44186094
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/981,058 Abandoned US20110155464A1 (en) | 2009-12-31 | 2010-12-29 | Method for the identification of the formation fluid invasion moment |
Country Status (4)
Country | Link |
---|---|
US (1) | US20110155464A1 (en) |
BR (1) | BRPI1005067A2 (en) |
MX (1) | MX2011000050A (en) |
RU (1) | RU2431035C2 (en) |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN102619503A (en) * | 2012-04-11 | 2012-08-01 | 上海大学 | Cable stratum tester |
CN104215405A (en) * | 2013-06-03 | 2014-12-17 | 中国石油天然气股份有限公司 | Seal checking method and seal checking tool for packer of layered water injection well |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN103806910A (en) | 2014-03-04 | 2014-05-21 | 中国海洋石油总公司 | Stratigraphic drilling sampling system |
Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20070151727A1 (en) * | 2005-12-16 | 2007-07-05 | Schlumberger Technology Corporation | Downhole Fluid Communication Apparatus and Method |
US20080041594A1 (en) * | 2006-07-07 | 2008-02-21 | Jeanne Boles | Methods and Systems For Determination of Fluid Invasion In Reservoir Zones |
US7445934B2 (en) * | 2006-04-10 | 2008-11-04 | Baker Hughes Incorporated | System and method for estimating filtrate contamination in formation fluid samples using refractive index |
-
2009
- 2009-12-31 RU RU2009149591/03A patent/RU2431035C2/en not_active IP Right Cessation
-
2010
- 2010-12-29 BR BRPI1005067-1A patent/BRPI1005067A2/en not_active Application Discontinuation
- 2010-12-29 US US12/981,058 patent/US20110155464A1/en not_active Abandoned
-
2011
- 2011-01-05 MX MX2011000050A patent/MX2011000050A/en not_active Application Discontinuation
Patent Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20070151727A1 (en) * | 2005-12-16 | 2007-07-05 | Schlumberger Technology Corporation | Downhole Fluid Communication Apparatus and Method |
US7445934B2 (en) * | 2006-04-10 | 2008-11-04 | Baker Hughes Incorporated | System and method for estimating filtrate contamination in formation fluid samples using refractive index |
US20080041594A1 (en) * | 2006-07-07 | 2008-02-21 | Jeanne Boles | Methods and Systems For Determination of Fluid Invasion In Reservoir Zones |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN102619503A (en) * | 2012-04-11 | 2012-08-01 | 上海大学 | Cable stratum tester |
CN104215405A (en) * | 2013-06-03 | 2014-12-17 | 中国石油天然气股份有限公司 | Seal checking method and seal checking tool for packer of layered water injection well |
Also Published As
Publication number | Publication date |
---|---|
BRPI1005067A2 (en) | 2013-04-16 |
RU2431035C2 (en) | 2011-10-10 |
RU2009149591A (en) | 2011-07-10 |
MX2011000050A (en) | 2011-06-29 |
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Legal Events
Date | Code | Title | Description |
---|---|---|---|
STCB | Information on status: application discontinuation |
Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION |