CA2032747C - Method of in-situ testing of a drilling fluid - Google Patents
Method of in-situ testing of a drilling fluid Download PDFInfo
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- CA2032747C CA2032747C CA002032747A CA2032747A CA2032747C CA 2032747 C CA2032747 C CA 2032747C CA 002032747 A CA002032747 A CA 002032747A CA 2032747 A CA2032747 A CA 2032747A CA 2032747 C CA2032747 C CA 2032747C
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- 239000012530 fluid Substances 0.000 title claims abstract description 125
- 238000005553 drilling Methods 0.000 title claims abstract description 63
- 238000000034 method Methods 0.000 title claims abstract description 24
- 238000012360 testing method Methods 0.000 title claims description 13
- 238000011065 in-situ storage Methods 0.000 title claims description 6
- 230000000704 physical effect Effects 0.000 claims abstract description 9
- 238000012544 monitoring process Methods 0.000 claims abstract 2
- 230000003068 static effect Effects 0.000 claims description 8
- 230000009974 thixotropic effect Effects 0.000 claims description 7
- 238000005086 pumping Methods 0.000 claims description 6
- 230000000630 rising effect Effects 0.000 claims description 5
- 238000001879 gelation Methods 0.000 claims description 3
- 230000003247 decreasing effect Effects 0.000 claims 1
- 239000007788 liquid Substances 0.000 abstract 1
- 238000005520 cutting process Methods 0.000 description 9
- 239000011435 rock Substances 0.000 description 6
- 238000010586 diagram Methods 0.000 description 3
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 239000004927 clay Substances 0.000 description 2
- 238000004140 cleaning Methods 0.000 description 2
- 230000007423 decrease Effects 0.000 description 2
- 230000002706 hydrostatic effect Effects 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
- 239000002671 adjuvant Substances 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 230000006641 stabilisation Effects 0.000 description 1
- 239000000725 suspension Substances 0.000 description 1
- 238000010998 test method Methods 0.000 description 1
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
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
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- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Mechanical Engineering (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Earth Drilling (AREA)
- Investigating Strength Of Materials By Application Of Mechanical Stress (AREA)
Abstract
The method comprises during a drilling operation wherein the drilling fluid is set moving and the drill string is stationary, monitoring the pressure of the drilling fluid pumped into the drill string depending on the volume of liquid pumped in the drill string and determining, from the pressure curve, a physical property linked to the thixotropy of the drilling fluid.
An advantage of the invention is that the highest point of the pressure curve indicating the start of the fluid flow into the well is easily visible, and its maximum value can be measured to find the gel strength specific value.
An advantage of the invention is that the highest point of the pressure curve indicating the start of the fluid flow into the well is easily visible, and its maximum value can be measured to find the gel strength specific value.
Description
METHOD OF IN-SITU TESTING OF A DF~,ILLL'~1G FLUID
This invention relates to a method of in situ testing; of a thixotropic drilling fluid during drilling of a well using a drilling tool with a drill bit and drill string formed from drill pipes joined together.
In the rotary drilling of an oil or geothermal well, a drill string is formed from a set of pipes joined together and a drill bit fitted at one end. The drill bit drills the rock when it starts rotating, either by rotating the drill string from the surface, or by using a hydraulic motor situated above the drill bit.
A drilling fluid, normally called "mud" is pumped from the surface inside the drill string, goes through the drill hit and comes back to the surface through the annulus existing between the wall of the well and the drill string. Mud is an important part of the drilling; process and is used for several purposes. One of them is to create hydrostatic pressure on the drill bit sufficient to counterbalance the pressure of the fluids present in the rocks which are being drilled. This hydrostatic pressure cannot be too high so as not to fracture the rock. The density of the mud must be maintained between minimum and maximum values. Another function of the mud is to bring back to the surface the rock cuttings which have just been drilled. For this the mud viscosity must be sufficient to keep the cuttings suspended. However, viscosity cannot be too high to prevent pumping and circulating of the drilling fluid in the well. In use, the drilling fluid is either stationary and has a tendency to gel or is circulated by means of a pump from the surface to the inside of the drill string and rises towards the surface in the annulus between the wall of the drilled well and the drill string assembly.
Every time drilling progresses in depth by one drial pipe length, fluid circulation must be stopped while another pipe is added to the drill string. During this operation the drilling fluid which is stationary in the well contains the cuttings that the fluid is bringing to the surface. To prevent these cuttings from going back to the bottom of the well a thixotropic fluid is used. The rheological properdies of the mud are affected by the drilling conditions such as temperature in the well anti the types of rocks drilled. As an example, when drilling a clay formation, the clay dissolves in the fluid increasing greatly the mud viscosity and the yield stress. It is therefore essential to test and control the drilling fluid properties so as to be able to modify its formula to maintain a chosen formula or modify it depending on the drilling conditions.
Normal practice on drilling sites is to take a sample of mud regularly and test its rheological properties, especially its viscosity. However these test conditions are not equivalent to the conditions prevailing in the well and do not reflect the state of the mud being used. This method is described in US patent 4,726,19 and GB patent - ~1-
This invention relates to a method of in situ testing; of a thixotropic drilling fluid during drilling of a well using a drilling tool with a drill bit and drill string formed from drill pipes joined together.
In the rotary drilling of an oil or geothermal well, a drill string is formed from a set of pipes joined together and a drill bit fitted at one end. The drill bit drills the rock when it starts rotating, either by rotating the drill string from the surface, or by using a hydraulic motor situated above the drill bit.
A drilling fluid, normally called "mud" is pumped from the surface inside the drill string, goes through the drill hit and comes back to the surface through the annulus existing between the wall of the well and the drill string. Mud is an important part of the drilling; process and is used for several purposes. One of them is to create hydrostatic pressure on the drill bit sufficient to counterbalance the pressure of the fluids present in the rocks which are being drilled. This hydrostatic pressure cannot be too high so as not to fracture the rock. The density of the mud must be maintained between minimum and maximum values. Another function of the mud is to bring back to the surface the rock cuttings which have just been drilled. For this the mud viscosity must be sufficient to keep the cuttings suspended. However, viscosity cannot be too high to prevent pumping and circulating of the drilling fluid in the well. In use, the drilling fluid is either stationary and has a tendency to gel or is circulated by means of a pump from the surface to the inside of the drill string and rises towards the surface in the annulus between the wall of the drilled well and the drill string assembly.
Every time drilling progresses in depth by one drial pipe length, fluid circulation must be stopped while another pipe is added to the drill string. During this operation the drilling fluid which is stationary in the well contains the cuttings that the fluid is bringing to the surface. To prevent these cuttings from going back to the bottom of the well a thixotropic fluid is used. The rheological properdies of the mud are affected by the drilling conditions such as temperature in the well anti the types of rocks drilled. As an example, when drilling a clay formation, the clay dissolves in the fluid increasing greatly the mud viscosity and the yield stress. It is therefore essential to test and control the drilling fluid properties so as to be able to modify its formula to maintain a chosen formula or modify it depending on the drilling conditions.
Normal practice on drilling sites is to take a sample of mud regularly and test its rheological properties, especially its viscosity. However these test conditions are not equivalent to the conditions prevailing in the well and do not reflect the state of the mud being used. This method is described in US patent 4,726,19 and GB patent - ~1-
2~3~"~~'~
1280,227. A method of in situ testing of the rheological properties of drilling fluids is described in the article "Surface recorder can signal downhole drilling problems" in World Oil (November 85 p71-77). However the rheological properties of a drilling fluid can only be tested when the mud is circulating.
This invention proposes a method of in situ testing of the drilling fluid which avoids the drawbacks of previous methods. To be more F~recise, this invention provides a test method for a thixotropic drilling fluid during drilling operations carried out with a drilling tool including a drill bit, a drill string assembly formed from drilling pipes joined together. The drilling fluid when stationary has a tendenctr to gel or the drilling fluid is being circulated by means of a pump from the siwface to the drill bit inside the drill string and rising towards the surface in the annular space provided between the wall of the well already drilled and the drill string. When the circulation is restarted, the drilling tool is stationary; the evolution in the pressure of the fluid being pumped in the drilling tool can be monitored. One aspect of the inventi',on is to be able to monitor the pressure peak corresponding to the start-up of fluid circulation in the well and to measure its maximum value so as to find the gel strength of the gelled mud.
A further aspect is the possibility of determining the yield strength and the compressibility of the gelled mud from the rising part c>f the pressure peak.
When the drilling tool starts rotating if the evolution of the fluid pressure is monitored with regard to the quantity of pumped fluid, two values of the physical properties can be obtained one dynamic when the drilling tool is rotating and the other static when the drilling tool is stationary.
A yet further aspect is the possibility of determining the asymptotic value of the down curve of the pressure peak. From this asymptotic 'value, the pressure drop due to fluid loss in the well can be determined. The operation can be repeated to follow the evolution of the pressure of the fluid being pumped compared to the quantity of fluid being pumped after the fluid has been stationary for a relatively constant period of time.
This operation can be repeated almost every time treat a drill pipe is added.
The successive evolutions of the pressure can be compared and the variations of the physical properties characteristic to the thixotropy of the drilling fluid can be found.
The invention will be better understood when reading the following description and the attached figures.
Figure 1 shows a sketch of a well being drilled and the surface equipment used for circulating and cleaning the drilling fluid.
Figure 2 a shows a rheogram of the mud i.e. the: shear stress ST, the shear rate SR and figure 2b represents the evolution of pressure p of the fluid being pumped in relation to the volume of the pumped fluid for different levels of mud gelation.
Figure 3 shows three diagrams, in terms of time, the number of pump cycles N, the flow rate Q and the pressure p of the pumped fluid when the drill pipe is being added.
Figure 4 shows the evolution of pressure p of the pumped fluid in relation to the number of pump cycles, drawn from figures 3a and c.
Figure 5 shows the evolution of pressure p in relation to the number of pump cycles N drawn from figure Sa and c.
Figure 1 shows a schematic of a drilling well (10) with a drill string (12) including drill pipes ( 14) and a drill bit ( 16). A drilling tower ( 18) allows handling of the drill string from the surface, particularly to add pipes to the drill string and to start rotating the drill string (16) to drill the rock. The drill bit rotation can also be carried out with a motor situated at the bottom, particularly when drilling deviated wells.
Every time the well is drilled for an additional dLepth of a pipe length, about 9 metres, a new pipe is added to the top end of the drill string on the surface.
The drilling of the well will start again until another length of pipe is drilled. This is done again until the drill string is removed from the well either because the drill bit is worn or because the desired depth has been reached. A drilling fluid generally called "mud" is kept in a mud tank (20). This fluid is circulated by a pump (22). The fluid possess up a rigid pipe (24), then a stand pipe (26) before being sent in the drill string from an injection head (30) connected to the stand pipe (26) by a flexible pipe (28). The first pipe (34) connected to the injection head (30) has a square section so that it can be rotated from a rotating table (not shown). The drill pipes added one after the other during drilling operations are fitted between the square pipe (34) and the drill string (12).
The drilling fluid circulates inside the drill string (12), then through the drill bit ( 16) via the injectors up to the surface in the annular space (3b) existing between the drill string and the wall of the well ( 10). At the surface, mud goes through a cleaning process (38) in which the cuttings (40) are separated from the mud which then returns through pipe 42 in the mud tank 20. New mud and/or adjuvants can be added in the tank through pipe 44. The cuttings 40 are sent through the pipe 46. The pumping equipment includes a sensor 48 recording pump cycles 22. Each pump cycle corresponds to a certain volume of fluid pumped in pipe 24. The number of cycles allows the determination of the volume of fluid pumpedl inside the drill string. A flow rate valve placed inside pipe 24 could be used instead of sensor 48 to measure the volume of fluid pumped inside the drill string. A pre;~sure sensor situated between pump 22 and the injection head measures the pressure of the fluid pumped inside the column. Sensors 48 and 50 are connected to a data recorder 52. This recorder allows, for example, real time recording of the evolution of the: pressure measured by sensor 50, as well as the number of pump strokes detected by sensor 48. This recorder also
1280,227. A method of in situ testing of the rheological properties of drilling fluids is described in the article "Surface recorder can signal downhole drilling problems" in World Oil (November 85 p71-77). However the rheological properties of a drilling fluid can only be tested when the mud is circulating.
This invention proposes a method of in situ testing of the drilling fluid which avoids the drawbacks of previous methods. To be more F~recise, this invention provides a test method for a thixotropic drilling fluid during drilling operations carried out with a drilling tool including a drill bit, a drill string assembly formed from drilling pipes joined together. The drilling fluid when stationary has a tendenctr to gel or the drilling fluid is being circulated by means of a pump from the siwface to the drill bit inside the drill string and rising towards the surface in the annular space provided between the wall of the well already drilled and the drill string. When the circulation is restarted, the drilling tool is stationary; the evolution in the pressure of the fluid being pumped in the drilling tool can be monitored. One aspect of the inventi',on is to be able to monitor the pressure peak corresponding to the start-up of fluid circulation in the well and to measure its maximum value so as to find the gel strength of the gelled mud.
A further aspect is the possibility of determining the yield strength and the compressibility of the gelled mud from the rising part c>f the pressure peak.
When the drilling tool starts rotating if the evolution of the fluid pressure is monitored with regard to the quantity of pumped fluid, two values of the physical properties can be obtained one dynamic when the drilling tool is rotating and the other static when the drilling tool is stationary.
A yet further aspect is the possibility of determining the asymptotic value of the down curve of the pressure peak. From this asymptotic 'value, the pressure drop due to fluid loss in the well can be determined. The operation can be repeated to follow the evolution of the pressure of the fluid being pumped compared to the quantity of fluid being pumped after the fluid has been stationary for a relatively constant period of time.
This operation can be repeated almost every time treat a drill pipe is added.
The successive evolutions of the pressure can be compared and the variations of the physical properties characteristic to the thixotropy of the drilling fluid can be found.
The invention will be better understood when reading the following description and the attached figures.
Figure 1 shows a sketch of a well being drilled and the surface equipment used for circulating and cleaning the drilling fluid.
Figure 2 a shows a rheogram of the mud i.e. the: shear stress ST, the shear rate SR and figure 2b represents the evolution of pressure p of the fluid being pumped in relation to the volume of the pumped fluid for different levels of mud gelation.
Figure 3 shows three diagrams, in terms of time, the number of pump cycles N, the flow rate Q and the pressure p of the pumped fluid when the drill pipe is being added.
Figure 4 shows the evolution of pressure p of the pumped fluid in relation to the number of pump cycles, drawn from figures 3a and c.
Figure 5 shows the evolution of pressure p in relation to the number of pump cycles N drawn from figure Sa and c.
Figure 1 shows a schematic of a drilling well (10) with a drill string (12) including drill pipes ( 14) and a drill bit ( 16). A drilling tower ( 18) allows handling of the drill string from the surface, particularly to add pipes to the drill string and to start rotating the drill string (16) to drill the rock. The drill bit rotation can also be carried out with a motor situated at the bottom, particularly when drilling deviated wells.
Every time the well is drilled for an additional dLepth of a pipe length, about 9 metres, a new pipe is added to the top end of the drill string on the surface.
The drilling of the well will start again until another length of pipe is drilled. This is done again until the drill string is removed from the well either because the drill bit is worn or because the desired depth has been reached. A drilling fluid generally called "mud" is kept in a mud tank (20). This fluid is circulated by a pump (22). The fluid possess up a rigid pipe (24), then a stand pipe (26) before being sent in the drill string from an injection head (30) connected to the stand pipe (26) by a flexible pipe (28). The first pipe (34) connected to the injection head (30) has a square section so that it can be rotated from a rotating table (not shown). The drill pipes added one after the other during drilling operations are fitted between the square pipe (34) and the drill string (12).
The drilling fluid circulates inside the drill string (12), then through the drill bit ( 16) via the injectors up to the surface in the annular space (3b) existing between the drill string and the wall of the well ( 10). At the surface, mud goes through a cleaning process (38) in which the cuttings (40) are separated from the mud which then returns through pipe 42 in the mud tank 20. New mud and/or adjuvants can be added in the tank through pipe 44. The cuttings 40 are sent through the pipe 46. The pumping equipment includes a sensor 48 recording pump cycles 22. Each pump cycle corresponds to a certain volume of fluid pumped in pipe 24. The number of cycles allows the determination of the volume of fluid pumpedl inside the drill string. A flow rate valve placed inside pipe 24 could be used instead of sensor 48 to measure the volume of fluid pumped inside the drill string. A pre;~sure sensor situated between pump 22 and the injection head measures the pressure of the fluid pumped inside the column. Sensors 48 and 50 are connected to a data recorder 52. This recorder allows, for example, real time recording of the evolution of the: pressure measured by sensor 50, as well as the number of pump strokes detected by sensor 48. This recorder also
- 3-allows to measure the evolution of the pressure related to the number of pump cycles.
One of the main functions of drilling mud is to carry the cuttings produced by drill bit from the bottom of the well to the surface through the annular space 36. Every time a drill pipe is added to the drill string 40, pump 22 is stopped and circulation of the mud is also stopped. When the mud is stationery, the cuttings. present in the annular space have a tendency to fall to the bottom of the well. In order to prevent such an inconvenience, a relatively viscous drilling fluid is usead to maintain the cuttings in suspension when the fluid is stationery. However, the viscosity of the mud cannot be too great from the pumping means to circulate the mud effectively in the well.
This is achieved by using a thixotropic drilling fluid, that is to say, a fluid in which the viscosity decreases when the fluid is placed in rotation or agitated. It is current practice in order to find the fluid behaviour to trace a rheogram showing the shear stress ST as opposed to the shear rate SR applied to the fluid. This behaviour is shown on figure 2a.
For this, a viscosimeter is used to submit the fluid being tested to a given shear rate and record the shear stress. The viscosimeter most often used in the Petroleum Industry is the FANN viscosimeter. It has two coaxial cylinders between v~hich is placed a mud sample to be tested. The mud shear stress is obtained by rotating one cylinder against the other, the shear stress is then defined by the strength necessary to apply to the other cylinder to stop rotation. Another type of viscosimeter is made of a narrow tube in which a mud sample circulates. The pressure difference is recorded (pl - p2) between the entry and exit of the fluid in and out of the viscosimeter as a function of flow rate Q.
For this type of viscosimeter, the shear stress is given by.;
ST = D (pl - P2)/4L
D and L being respectively the diameter and the length of the viscosimeter.
The shear rate SR is given by SR = 32Q/3,14 D3 The rheogram on figure 2 of the shear stress ST of the shear rate SR is equivalent to a diagram showing the variation of the fluid pressure in relation to flow rate Q, knowing the shape of the tube in which the fluid circulates.
The rheogram on figure 2 is typical of a non-newtonian fluid; to activate this _ fluid it is necessary to submit it to a minimum shear stress STp, called yield stress.
With a shear stress higher than STp, the fluid is circulating. The slope of the curve ST
compared to SR is, by definition, the apparent viscosity of the fluid. However for
One of the main functions of drilling mud is to carry the cuttings produced by drill bit from the bottom of the well to the surface through the annular space 36. Every time a drill pipe is added to the drill string 40, pump 22 is stopped and circulation of the mud is also stopped. When the mud is stationery, the cuttings. present in the annular space have a tendency to fall to the bottom of the well. In order to prevent such an inconvenience, a relatively viscous drilling fluid is usead to maintain the cuttings in suspension when the fluid is stationery. However, the viscosity of the mud cannot be too great from the pumping means to circulate the mud effectively in the well.
This is achieved by using a thixotropic drilling fluid, that is to say, a fluid in which the viscosity decreases when the fluid is placed in rotation or agitated. It is current practice in order to find the fluid behaviour to trace a rheogram showing the shear stress ST as opposed to the shear rate SR applied to the fluid. This behaviour is shown on figure 2a.
For this, a viscosimeter is used to submit the fluid being tested to a given shear rate and record the shear stress. The viscosimeter most often used in the Petroleum Industry is the FANN viscosimeter. It has two coaxial cylinders between v~hich is placed a mud sample to be tested. The mud shear stress is obtained by rotating one cylinder against the other, the shear stress is then defined by the strength necessary to apply to the other cylinder to stop rotation. Another type of viscosimeter is made of a narrow tube in which a mud sample circulates. The pressure difference is recorded (pl - p2) between the entry and exit of the fluid in and out of the viscosimeter as a function of flow rate Q.
For this type of viscosimeter, the shear stress is given by.;
ST = D (pl - P2)/4L
D and L being respectively the diameter and the length of the viscosimeter.
The shear rate SR is given by SR = 32Q/3,14 D3 The rheogram on figure 2 of the shear stress ST of the shear rate SR is equivalent to a diagram showing the variation of the fluid pressure in relation to flow rate Q, knowing the shape of the tube in which the fluid circulates.
The rheogram on figure 2 is typical of a non-newtonian fluid; to activate this _ fluid it is necessary to submit it to a minimum shear stress STp, called yield stress.
With a shear stress higher than STp, the fluid is circulating. The slope of the curve ST
compared to SR is, by definition, the apparent viscosity of the fluid. However for
- 4-~~~7~' thixotropic fluids such as drilling mud which have a tendency to gel when stationary , the shear rate ST necessary to activate the fluid is higher than the yield stress STO. This shear stress, called gel strength is indicated by point A on the rheogram of figure 2a.
When the gel strength of the gelled fluid is reached, the shear stress decreases rapidly down to point B to follow the curve shown on figure 2a.
In this invention, when the circulation of the fJluid is started again with the pumping unit, the evolution of the pressure of the fluid pumped in the drill string in relation to the number of pump cycles can be clearly seen, taking into account the volume of the fluid pumped in the drill string and with the; drilling fluid being stationary at the beginning of the experiment. The presswe curve reaches a maximum at gel breaking point i.e, at gel strength of the gelled fluid. This defines the physical property of the thixotropy of a drilling fluid. In good conditions, this presswe test is carried out after having added a pipe to the drill string when circulating by pumping is resumed. If this test is carried out regularly and if the period during which the fluid remains stationary is kept constant, it is possible to follow the evolution of the physical property of the drilling fluid thixotropy and particularly the evolution of the gel strength gelled during its life in the well.
Figure 2b shows the evolution of the fluid pressure measured by sensor 50 from the number of pump cycles of pump N measured by sensor 48 with the the fluid being stationary. The curve 60 shows the evolution of the presswe for a non-gelled fluid. The curve reaches its asymptotic value pa showing the pressure drop in the drill string and in the annulus corresponding to the smallest flow rate of the fluid. The cwve 62 shows the evolution of the pressure related to the number of pump strokes N, for a gelled fluid and resuming of circulation. The drill string is stationary. The presswe reaches a peak 64 when the number of pump strokes is equal to 8 when a certain amount of fluid is injected in the drill string. Before reaching this peak, i.e. n=8, the gelled fluid is stationary. When maximum pressure is. reached, the gel breaks and pressure drops rapidly (curve 66) to reach the asymptotic value pa. The highest pressure pm corresponds to the gel strength of the gelled fluid. The maximum value varies from the degree of gelation of the gel which increases rapidly when circulation of the fluid stops to reach a stabilised value after a while. To compare the gel strength of two types of fluids or to follow the evolution of the gel strength of a gelled fluid during its utilization, the successive presswe tests (curve 62, figure 2b) must be done while the fluid is stationary during a relatively constant period of time before each test. The rising part between N=0 and N=8 shows the elasticity and compressibility of the gelled fluid. Curve 68 shows the evolution of the presswe for the same gelled fluid as in curve 62 but the drill string is rotating at more or less constant speed. If the rotation speed o-f the drill string is fairly low, and the fluid inside the drill string is considered as
When the gel strength of the gelled fluid is reached, the shear stress decreases rapidly down to point B to follow the curve shown on figure 2a.
In this invention, when the circulation of the fJluid is started again with the pumping unit, the evolution of the pressure of the fluid pumped in the drill string in relation to the number of pump cycles can be clearly seen, taking into account the volume of the fluid pumped in the drill string and with the; drilling fluid being stationary at the beginning of the experiment. The presswe curve reaches a maximum at gel breaking point i.e, at gel strength of the gelled fluid. This defines the physical property of the thixotropy of a drilling fluid. In good conditions, this presswe test is carried out after having added a pipe to the drill string when circulating by pumping is resumed. If this test is carried out regularly and if the period during which the fluid remains stationary is kept constant, it is possible to follow the evolution of the physical property of the drilling fluid thixotropy and particularly the evolution of the gel strength gelled during its life in the well.
Figure 2b shows the evolution of the fluid pressure measured by sensor 50 from the number of pump cycles of pump N measured by sensor 48 with the the fluid being stationary. The curve 60 shows the evolution of the presswe for a non-gelled fluid. The curve reaches its asymptotic value pa showing the pressure drop in the drill string and in the annulus corresponding to the smallest flow rate of the fluid. The cwve 62 shows the evolution of the pressure related to the number of pump strokes N, for a gelled fluid and resuming of circulation. The drill string is stationary. The presswe reaches a peak 64 when the number of pump strokes is equal to 8 when a certain amount of fluid is injected in the drill string. Before reaching this peak, i.e. n=8, the gelled fluid is stationary. When maximum pressure is. reached, the gel breaks and pressure drops rapidly (curve 66) to reach the asymptotic value pa. The highest pressure pm corresponds to the gel strength of the gelled fluid. The maximum value varies from the degree of gelation of the gel which increases rapidly when circulation of the fluid stops to reach a stabilised value after a while. To compare the gel strength of two types of fluids or to follow the evolution of the gel strength of a gelled fluid during its utilization, the successive presswe tests (curve 62, figure 2b) must be done while the fluid is stationary during a relatively constant period of time before each test. The rising part between N=0 and N=8 shows the elasticity and compressibility of the gelled fluid. Curve 68 shows the evolution of the presswe for the same gelled fluid as in curve 62 but the drill string is rotating at more or less constant speed. If the rotation speed o-f the drill string is fairly low, and the fluid inside the drill string is considered as
- 5-turning together with the drill string when the fluid in the; annulus is agitated, the gel in the annulus is broken. The difference in the pressure indicated in 70 on figure 2b is then the gel strength of the gelled fluid in the drill string. The difference of pressure Pm-Pa, indicated in 72, indicates the static gel strength of the gelled fluid in the drill string and in the annulus. The following figures illustrate the invention with measurements taken during drilling operations. The diagram of figure 3 and 5 were recorded as per time and indicated in seconds. The pump is started again at time t0 at slow speed with a small flow. From time tl the number of pump strokes increases.
Figure 3b, which shows the flow Q in relation to time, is no less than the integral of the number of pump cycles of figure 3a in relation to time. The flow is indicated in litres per minute. Between time to and tl, the flow Q is small and constant.
It increases rapidly at time tl to reach stabilisation at a relatively constant value. On figure 3c, it can be seen that pressure p, indicated in MPa goes to a maximum between time t0 and tl. This maximum 80 is the yield point of the gelled fluid. Pressure then rises rapidly to stabilise at a relatively constant value.
Figure 4 shows the evolution of the pressure p of the pumped fluid related to the number of pump cycles N. The curve was made by combining figure 3a and 3c.
Pressure is relatively stable around 1 MPa, until a number of pump cycles of around 10. This number of pump cycles corresponds to the volume of fluid necessary to inject in the drill string to compress the air sent in the drill string when a pipe is added. A
pressure peak 82 happens, shown by a rapid increase of pressure 84 followed by a drop 86 until a number of pump cycles of 22. Then, pressure increases rapidly (part of curve 88) until it stabilises. The maximum 82 of the pressure peak corresponds to the breaking point of the gelled fluid or its gel strength. As long as maximum 82 of the pressure has not been reached, the fluid remains stationary in the well. It only starts circulating again when maximum 82 is reached. If the; driller had not increased the pumps flow from the number of cycles N=22, the pressure drop 86 would have stabilised until reaching a plateau 90.
The data on figure 5 were recorded during the same well as figure 3, and with the same type of drilling fluid, but two and a half hours :later. Fiwres Sa, b and c show respectively the number of pump cycles N, the flow Q in litres per minute and the pressure p in MPa, recorded as per time t. The pump is restarted at time to.
On figure Sb the successive flow rate in seconds are indicated between time tp, tl, t2 and t3. On y figure Sc, a pressure peak 92 appears at time t0.
The curve on figure 6 showing the evolution of the pressure in relation to the number of pump cycles was done by combining the figure Sa and Sc curves. On figure
Figure 3b, which shows the flow Q in relation to time, is no less than the integral of the number of pump cycles of figure 3a in relation to time. The flow is indicated in litres per minute. Between time to and tl, the flow Q is small and constant.
It increases rapidly at time tl to reach stabilisation at a relatively constant value. On figure 3c, it can be seen that pressure p, indicated in MPa goes to a maximum between time t0 and tl. This maximum 80 is the yield point of the gelled fluid. Pressure then rises rapidly to stabilise at a relatively constant value.
Figure 4 shows the evolution of the pressure p of the pumped fluid related to the number of pump cycles N. The curve was made by combining figure 3a and 3c.
Pressure is relatively stable around 1 MPa, until a number of pump cycles of around 10. This number of pump cycles corresponds to the volume of fluid necessary to inject in the drill string to compress the air sent in the drill string when a pipe is added. A
pressure peak 82 happens, shown by a rapid increase of pressure 84 followed by a drop 86 until a number of pump cycles of 22. Then, pressure increases rapidly (part of curve 88) until it stabilises. The maximum 82 of the pressure peak corresponds to the breaking point of the gelled fluid or its gel strength. As long as maximum 82 of the pressure has not been reached, the fluid remains stationary in the well. It only starts circulating again when maximum 82 is reached. If the; driller had not increased the pumps flow from the number of cycles N=22, the pressure drop 86 would have stabilised until reaching a plateau 90.
The data on figure 5 were recorded during the same well as figure 3, and with the same type of drilling fluid, but two and a half hours :later. Fiwres Sa, b and c show respectively the number of pump cycles N, the flow Q in litres per minute and the pressure p in MPa, recorded as per time t. The pump is restarted at time to.
On figure Sb the successive flow rate in seconds are indicated between time tp, tl, t2 and t3. On y figure Sc, a pressure peak 92 appears at time t0.
The curve on figure 6 showing the evolution of the pressure in relation to the number of pump cycles was done by combining the figure Sa and Sc curves. On figure
6, pressure is relatively constant, at 1 MPa, until the number of pump cycles equals to - 15. This part of the curve shows the air being compressed in the drill string. The pressure then increases rapidly, curie 9b, until a maximum value of 4 MPa for a number of pump cycles equal to 20. This rise in pressure indicates the elasticity and compressibility of the gelled fluid. The maximum of the pressure, indicated in 94, is the gel breaking point and the moment from which the fluid is. recirculated in the well.
The pressure then drops to an asymptotic value of approximately 3 MPa. The difference between maximum value of 4 MPa and the asymptotic value of 3 MPa is the static gel strength of the fluid gelled at 1 MPa. Between time t2 and t3, the pump flow is changeable. After time t3, pressure increases rapidly.
The comparison between pressure peaks 82 (figure 4) and 94 (figure 6) allows the definition of the changes of the thixotropic properties of the drilling fluid in relation to time. The peak maximum values allow the comparison of the different gel strengths of the gelled fluids, the asymptotic values (90 on figure 4 and 98 on figure 6) allow the comparison of the loss of fluid in the well and the differences between the peak maximum values and the asymptotic values allows the definition of the changes in the static gel strength of the gelled fluid. The pressure rises shown at 84 on figure 4 and 96 on figure 6 allow the evolution of the elasticity and compressibility of the gelled fluid to be followed.
The found values, such as the gel strength of the gelled fluid can be compared one against the other but can also be compared against a predetermined value.
If, for example, the gel strength of the gelled mud must not exceed a set value, and if the measurements done with this invention show that the value has been exceeded , or is going to be exceeded, the mud formula can be modified to bring the mud properties to the planned specifications. If necessary, changes can be made to allow for the increase in the drill string length as pipes are gradually added.
The pressure then drops to an asymptotic value of approximately 3 MPa. The difference between maximum value of 4 MPa and the asymptotic value of 3 MPa is the static gel strength of the fluid gelled at 1 MPa. Between time t2 and t3, the pump flow is changeable. After time t3, pressure increases rapidly.
The comparison between pressure peaks 82 (figure 4) and 94 (figure 6) allows the definition of the changes of the thixotropic properties of the drilling fluid in relation to time. The peak maximum values allow the comparison of the different gel strengths of the gelled fluids, the asymptotic values (90 on figure 4 and 98 on figure 6) allow the comparison of the loss of fluid in the well and the differences between the peak maximum values and the asymptotic values allows the definition of the changes in the static gel strength of the gelled fluid. The pressure rises shown at 84 on figure 4 and 96 on figure 6 allow the evolution of the elasticity and compressibility of the gelled fluid to be followed.
The found values, such as the gel strength of the gelled fluid can be compared one against the other but can also be compared against a predetermined value.
If, for example, the gel strength of the gelled mud must not exceed a set value, and if the measurements done with this invention show that the value has been exceeded , or is going to be exceeded, the mud formula can be modified to bring the mud properties to the planned specifications. If necessary, changes can be made to allow for the increase in the drill string length as pipes are gradually added.
Claims (13)
1 A method of in situ testing of a thixotropic drilling fluid used during the drilling of a well, said drilling comprising using a drill string assembly including a drill bit, and drill pipes joined together and said drilling fluid which is being either stationary in which state it has a tendency to gel or is circulated by means of a pumping unit from the surface to the drill bit inside the drill string and rising to the surface through an annular space defined between a wall of the well already drilled and the drill string; the method comprising monitoring of such fluid in a stationery state for a period of time after which circulation of the drilling fluid is restarted and the evolution of the pressure of the fluid pumped in the drill string is followed with regard to the volume of the fluid being pumped and the physical property of the thixotropy of the fluid is defined.
2 A method as claimed in claim 1, wherein a pressure peak occurring when the fluid circulation in the well is restarted is observed and used to define said property.
3 A method as claimed in claim 2, wherein the maximum value of the pressure peak is measured and a characteristic value of the gel strength of the gelled fluid is determined therefrom.
4 A method as claimed in claim 2, wherein the characteristic value of the gelled fluid elasticity is defined from a rising part of the pressure peak.
A method as claimed in claim 1, wherein the evolution of the fluid pressure with regard to the volume of fluid being pumped when the drill string is stationary and when it is rotating is monitored so as to find the values of the fluid physical property, a dynamic value when the drill string is rotating and a static value when the drill string is stationary.
6 A method as claimed in claim 5, wherein the difference between the static and the dynamic values is determined.
7 A method as claimed in claim 5, wherein the rotation speed of the drill string is set so that the drilling fluid inside the drill string circulates together with the drill string and that the drilling fluid inside the annular space is circulated to stop the gelation of the fluid.
8 A method as claimed in claim 6, wherein the gel strength of the fluid in the annular space is defined from the difference between the dynamic and static values.
9 A method as claimed in claim 2, wherein a asymptotic value of a decreasing part of the pressure peak is defined.
A method as claimed in claim 9, wherein loss of fluid due to leakage in the well is determined from the asymptotic value.
11 A method as claimed in claim 9, wherein the static value of the fluid gel strength is determined by subtracting the asymptotic value from the maximum pressure peak value.
12 A method as claimed in claim 1, wherein the operation of following the evolution of the pressure of the pumped fluid with regard to its volume after the fluid has been stationary during a relatively constant period of time is repeated regularly after having added a drill pipe so as to define the changes in the physical property linked to the thixotropy of the drilling fluid.
13 A method as claimed in claim 12, wherein the drilling fluid formula is adjusted when the above changes in the physical property rise above a set value.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| FR8917294A FR2656373B1 (en) | 1989-12-26 | 1989-12-26 | IN SITU TEST METHOD OF A DRILLING FLUID. |
| FR8917294 | 1989-12-26 |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2032747A1 CA2032747A1 (en) | 1991-06-27 |
| CA2032747C true CA2032747C (en) | 2002-03-12 |
Family
ID=9389041
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002032747A Expired - Fee Related CA2032747C (en) | 1989-12-26 | 1990-12-19 | Method of in-situ testing of a drilling fluid |
Country Status (6)
| Country | Link |
|---|---|
| US (1) | US5042296A (en) |
| EP (1) | EP0435363B1 (en) |
| CA (1) | CA2032747C (en) |
| DE (1) | DE69026915D1 (en) |
| FR (1) | FR2656373B1 (en) |
| NO (1) | NO178310C (en) |
Families Citing this family (17)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB9601362D0 (en) * | 1996-01-24 | 1996-03-27 | Anadrill Int Sa | Method and apparatus for determining fluid influx during drilling |
| GB2337822B (en) * | 1998-05-26 | 2002-04-24 | Univ Sheffield | Material characterisation |
| US6659197B2 (en) * | 2001-08-07 | 2003-12-09 | Schlumberger Technology Corporation | Method for determining drilling fluid properties downhole during wellbore drilling |
| FR2831270B1 (en) * | 2001-10-19 | 2005-01-21 | Inst Francais Du Petrole | CONTINUOUS MEASUREMENTS OF THE RHEOLOGICAL CHARACTERISTICS OF WELL FLUIDS |
| US7036362B2 (en) * | 2003-01-20 | 2006-05-02 | Schlumberger Technology Corporation | Downhole determination of formation fluid properties |
| US7857046B2 (en) * | 2006-05-31 | 2010-12-28 | Schlumberger Technology Corporation | Methods for obtaining a wellbore schematic and using same for wellbore servicing |
| US8051910B2 (en) * | 2008-04-22 | 2011-11-08 | Baker Hughes Incorporated | Methods of inferring flow in a wellbore |
| DK201370421A1 (en) * | 2013-08-01 | 2015-02-09 | Mærsk Olie Og Gas As | Method of determining well productivity along a section of a wellbore |
| EP3143247B1 (en) * | 2014-05-14 | 2022-04-06 | Board of Regents, The University of Texas System | Systems and methods for determining a rheological parameter |
| US10539002B2 (en) * | 2015-05-01 | 2020-01-21 | Halliburton Energy Services, Inc. | In-line viscometer for measuring the viscosity of drilling fluids |
| US10695729B2 (en) * | 2016-03-24 | 2020-06-30 | Highland Fluid Technology, Inc. | Optimizing drilling mud shearing |
| CN105863531A (en) * | 2016-05-27 | 2016-08-17 | 安徽科恩新能源有限公司 | Slurry collection device of ground source heat pump |
| AU2017319326A1 (en) * | 2016-08-31 | 2019-04-18 | Board Of Regents, The University Of Texas System | Systems and methods for determining a fluid characteristic |
| US10519731B2 (en) | 2017-08-18 | 2019-12-31 | Schlumberger Technology Corporation | Evaluation and model of solids control equipment |
| US10689978B2 (en) * | 2018-05-31 | 2020-06-23 | Saudi Arabian Oil Company | Method for determining gelation time in a core plug |
| NO347449B1 (en) * | 2020-02-24 | 2023-11-06 | Norce Innovation As | Determining rheological properties of fluids |
| US11614391B1 (en) | 2021-10-27 | 2023-03-28 | Saudi Arabian Oil Company | Evaluating gel stability by injection in alternating flow directions |
Family Cites Families (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| AU449045B2 (en) * | 1969-06-24 | 1974-05-13 | Means for continuously monitoring the density, flow properties, gel strength resistivity, and ph properties of drilling mud | |
| DE2953152C1 (en) * | 1978-09-22 | 1984-11-29 | Sredneaziatskij naučno-issledovatel'skij institut prirodnogo gaza, Taškent | Method for determining the coagulation value of a drilling fluid and device for carrying out the method |
| US4274283A (en) * | 1978-10-16 | 1981-06-23 | Exxon Production Research Company | Apparatus and method for measuring fluid gel strength |
| FR2493927A1 (en) * | 1980-11-13 | 1982-05-14 | Petroles Cie Francaise | Data control and display system - for drilling mud and borehole cementing operations |
| US4726219A (en) * | 1986-02-13 | 1988-02-23 | Atlantic Richfield Company | Method and system for determining fluid pressures in wellbores and tubular conduits |
| US4694692A (en) * | 1986-06-04 | 1987-09-22 | Technical Oil Tools Corporation | Drilling fluid density measurement system |
| GB2200933B (en) * | 1987-02-10 | 1990-10-03 | Forex Neptune Sa | Drilling fluid |
-
1989
- 1989-12-26 FR FR8917294A patent/FR2656373B1/en not_active Expired - Lifetime
-
1990
- 1990-12-05 EP EP90203201A patent/EP0435363B1/en not_active Expired - Lifetime
- 1990-12-05 DE DE69026915T patent/DE69026915D1/en not_active Expired - Lifetime
- 1990-12-12 US US07/626,492 patent/US5042296A/en not_active Expired - Lifetime
- 1990-12-19 CA CA002032747A patent/CA2032747C/en not_active Expired - Fee Related
- 1990-12-21 NO NO905571A patent/NO178310C/en unknown
Also Published As
| Publication number | Publication date |
|---|---|
| NO178310B (en) | 1995-11-20 |
| NO905571D0 (en) | 1990-12-21 |
| DE69026915D1 (en) | 1996-06-13 |
| EP0435363B1 (en) | 1996-05-08 |
| NO178310C (en) | 1996-02-28 |
| FR2656373A1 (en) | 1991-06-28 |
| FR2656373B1 (en) | 1992-04-24 |
| US5042296A (en) | 1991-08-27 |
| CA2032747A1 (en) | 1991-06-27 |
| NO905571L (en) | 1991-06-27 |
| EP0435363A1 (en) | 1991-07-03 |
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