CN106368607B - Implement the method for kill-job using the system for implementing kill-job in deepwater dual gradient drilling - Google Patents
Implement the method for kill-job using the system for implementing kill-job in deepwater dual gradient drilling Download PDFInfo
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- 238000005553 drilling Methods 0.000 title claims abstract description 128
- 238000000034 method Methods 0.000 title claims abstract description 27
- 230000009977 dual effect Effects 0.000 title claims abstract description 13
- 238000002347 injection Methods 0.000 claims abstract description 36
- 239000007924 injection Substances 0.000 claims abstract description 36
- 239000012530 fluid Substances 0.000 claims description 93
- 230000002147 killing effect Effects 0.000 claims description 36
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 22
- 239000013535 sea water Substances 0.000 claims description 11
- 238000006073 displacement reaction Methods 0.000 claims description 7
- 230000001276 controlling effect Effects 0.000 claims description 3
- 230000001105 regulatory effect Effects 0.000 claims description 3
- 239000000203 mixture Substances 0.000 claims description 2
- 238000010992 reflux Methods 0.000 abstract 1
- 238000005516 engineering process Methods 0.000 description 5
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- 238000012806 monitoring device Methods 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 2
- 230000000903 blocking effect Effects 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
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- 238000007667 floating Methods 0.000 description 1
- 230000002706 hydrostatic effect Effects 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
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Abstract
The present invention proposes a kind of method for implementing kill-job using the system for implementing kill-job in deepwater dual gradient drilling.The system includes drilling platforms, marine riser, rotary flow divider, the preventer for being connected to rotary flow divider bottom, drilling rod, reflux pipeline, choke flow line and additional injection pipeline, wherein, marine riser is extended downwardly by drilling platforms, preventer is arranged at subsea wellheads, and additional injection pipeline can be connected to choke flow line.Double gradient kill-jobs can be carried out by the system, and improve the safety of deepwater dual gradient drilling operation.
Description
Technical Field
The invention relates to the petroleum drilling industry, in particular to a method for implementing well killing by using a system for implementing well killing in deep-water double-gradient drilling.
Background
In deep water and ultra-deep water drilling, the stratum fracture pressure is low and the safe density window is narrow due to the loss of overburden pressure in a seawater section. The conventional single-gradient drilling technology is adopted in deep water and ultra-deep water environments, the number of layers of casings needing to be put in is large, the requirement on control of annular Equivalent Circulating Density (ECD) is high in the drilling process, underground complexity and accidents are easy to happen, and great risks and challenges are brought to deep water drilling. The dual gradient drilling technology is a drilling technology developed in the later 90 s of the last century, and the key of the technology is that: by adopting different implementation modes, the annular pressure at the position of the seabed wellhead is reduced to be equal to or close to the pressure of a seawater hydrostatic column at the same depth (the equivalent drilling fluid density at the position of the seabed is equal to the seawater density), so that the pressure change curve in the annular space of the well casing can be better adapted to the change trend of a deep water stratum safety density window, the running depth of each layer of casing is further increased, particularly in a surface well section, the well structure is simplified, underground complex conditions and accidents such as well kick, well leakage and the like in the drilling process are reduced, and the risk and the cost of deep water drilling are reduced.
In the prior art, the double-gradient drilling technology can be adopted to better control the bottom pressure in the drilling process, and the occurrence risk of complex conditions in the well such as well kick and the like is reduced. However, due to the complexity of the formation pressure system and limitations on the accuracy of the formation pressure profile prediction, as well as other possible factors present during operation. The risk of well control operation by the conventional method is still high, especially under the condition of serious overflow.
Therefore, there is a need to design a system and method for performing kill operations in deep water dual gradient drilling to effectively control oil and gas well pressure control problems.
Disclosure of Invention
Aiming at the technical problems in the prior art, the invention provides a method for killing a well by using a system for killing the well in deep-water dual-gradient drilling. The system reduces the risk of leaking the drilled open hole stratum in the process of realizing the dual-gradient well killing, and improves the safety of the deepwater dual-gradient well drilling operation.
According to a first aspect of the present invention, there is provided a system for performing kill in deep water dual gradient drilling, comprising:
the drilling platform is provided with a drilling platform,
a riser extending downwardly from the drilling platform,
the top of the rotary flow divider is connected with a riser,
a blowout preventer connected to the bottom of the rotary diverter, the blowout preventer being arranged at the wellhead on the seabed,
a drill pipe extending downwards from the drilling platform, the drill pipe extending downwards sequentially through the riser, the rotary flow divider and the blowout preventer, the drill pipe and the riser forming a first annulus, the drill pipe and the wellbore forming a second annulus,
a return line extending downwardly from the drilling platform, the return line capable of communicating with the rotary diverter,
a choke line extending downwardly from the drilling platform, the choke line being communicable with the second annulus,
an additional injection line extending downwardly from the drilling platform, the additional injection line being communicable with the choke line.
In one embodiment, the additional injection pipe is communicable with the choke line at a lower end of the choke line.
In one embodiment, a flow regulator is provided at the upper end of the choke line for regulating the flow through the choke line. Preferably, the flow regulator is a throttle valve.
In one embodiment, a pump is provided at the upper opening of the additional injection line.
In one embodiment, the additional injection line can be in selective communication with the first annulus.
In one embodiment, the system further comprises a kill line capable of communicating with the second annulus, the kill line configured to deliver drilling fluid for killing the well bore into the well bore when the well is shut in empty or when the pipe is shut in sheared.
In one embodiment, a control assembly is also included, the control assembly being capable of controlling the blowout preventer and the rotary diverter.
According to a second aspect of the present invention, there is provided a method of performing kill in deep water dual gradient drilling, comprising the steps of:
1) when the overflow happens, the blowout preventer is operated to shut in the well, and the well shut-in casing pressure P is obtaineda1And shut-in vertical pressure PspAnd calculating the required equivalent weight well killing fluid density rhokeAnd actual kill fluid density ρk，
Equivalent weight kill fluid density
Obtaining the actual well killing fluid density
Where ρ ismAs the density of the original drilling fluid, HwTo the depth of the operating water, HbFor the depth at which the overflow occurs (measured downwards from the subsea location), ρwIs the density of seawater;
2) circulating for the first circle to kill the wellkFeeding the original drilling fluid into the wellbore through the drill pipe, and simultaneously opening the additional injection line to discharge a volume Qlm1Feeding the throttling pipeline with the density of rholmThe low-density drilling fluid enables the low-density drilling fluid to be mixed with the drilling fluid returned from the shaft and then return upwards, and the density of the mixed drilling fluid is rhox1During this process, the riser pressure is kept constant and equal to the initial cycle riser pressure Pspci，
Required discharge capacity of low-density drilling fluid
Density of mixed drilling fluid
The calculation formula of the initial circulating vertical pressure is Pspci＝Psp+ΔPci，
Wherein Q isk1/3-1/2 of normal drilling displacement, delta PciThe circulating pressure loss of the original drilling fluid under the well killing discharge capacity is realized;
3) circulating for the second week to kill the wellkFeeding a density p into the wellbore through the drill pipekOf the additional injection line is opened to discharge Qlm1Feeding the mixture with a density of rho into a throttling pipelinelmThe low-density drilling fluid enables the low-density drilling fluid to be mixed with the drilling fluid returned from the shaft and then return upwards, and the density of the mixed drilling fluid is rhox2Maintaining casing pressure until the kill fluid reaches the bit, and then increasing displacement until Qlm2Continuously feeding the throttling pipeline with the density of rholmWhile maintaining the riser pressure constant and equal to the final circulating vertical pressure PspcfUntil the well killing fluid returns to the throttling pipeline,
low-density drilling fluidRequired displacement
The calculation formula of the final circulating vertical pressure is
In one embodiment, between steps 2) and 3), the actual kill fluid density ρ is followedkAnd (4) preparing the well killing fluid.
In one embodiment, the choke line is filled with a density p during drilling prior to step 1)wAnd after step 3) the choke line is filled with seawater via an additional injection line.
Compared with the prior art, the system and the method for carrying out the well killing operation in the deepwater dual-gradient well drilling have the advantage that the dual-gradient well killing effect can be carried out under the condition of large overflow quantity. Meanwhile, the method can reduce the risk of leaking the drilled open hole section. Therefore, a well control means of the dual-gradient well drilling is added, and the safety of the deep-water dual-gradient well drilling operation is improved.
Drawings
Preferred embodiments of the present invention will be described in detail below with reference to the accompanying drawings. In the figure:
fig. 1 shows a block diagram of a system for dual gradient drilling using deep water according to the present invention.
The figures are not drawn to scale.
Detailed Description
The invention will be further explained with reference to the drawings.
FIG. 1 shows a system 100 for performing a kill operation in deep water dual gradient drilling in accordance with the present invention. As shown in fig. 1, the system 100 includes a drilling platform 1, a riser 2, a rotary diverter 4, a blowout preventer 5, a drill pipe 3, a return line 11, and a choke line 13. The drilling platform 1 may be constructed, among other things, as one or more floating drilling platforms. But may of course also be constructed as a semi-submersible rig. A riser 2 extends downwardly from the rig 1 and is connected to a rotary diverter 4 to guide a drill bit 7 and other drilling tools extending downwardly from the rig 1. The riser 2 may be made up of a number of pipe sections, each of which is a casing with connecting equipment. A blowout preventer 5 is provided at the lower end of the rotary diverter 4 at a subsea wellhead location. The drill pipe 3 extends in turn downwards through the riser 2, the rotary flow diverter 4 and the blowout preventer 5, and the drill pipe 3 forms a first annulus 18 with the riser 2 and a second annulus 19 with the wellbore 6. The return line 11 can be in communication with the rotary diverter 4 so that during normal drilling, drilling fluid returned by the second annulus 19 can be returned to the drilling platform 1 through the return line 11. The choke line 13 can communicate with the second annulus 19 so that drilling fluid can be circulated out of the wellbore 6 during kill. To achieve dual gradient kill operations, the system 100 also includes an additional injection line 14. The additional injection line 14 can communicate with the throttle line 13.
During normal drilling, the additional injection line 14 is filled with seawater. When well kick and the like occur and dual-gradient well killing operation needs to be carried out, low-density drilling fluid can be sent into the additional injection pipeline 14, enters the throttling pipeline 13 and is mixed with drilling fluid returned from the second annular space 19, so that the density of the mixed drilling fluid is reduced to a proper density, and therefore, in the well killing process, the drilling fluid or the killing fluid with higher density is in the second annular space 19, and the mixed drilling fluid with lower density is in the throttling pipeline 13. Thus, the system can realize double-gradient well killing. Meanwhile, due to the arrangement of the additional injection pipeline 14, the density of the mixed liquid in the throttling pipeline 13 can be adjusted to ensure that the density is in a proper range, so that the well killing requirement is met, and the drilled open hole section is not crushed and leaked. Thus, the system 100 facilitates enhanced safety in deepwater dual gradient drilling.
During normal drilling, the drilling fluid passes through the drill pipe valve 8 at the lower end of the drill pipe 3 to the drill bit 7 and finally into the second annulus 19. Due to the action of the rotary diverter 4, the drilling fluid in the second annulus 19 is redirected to return to the drilling platform 1 via the return line 11. A subsea pump package 12 may be provided on the return line 11 near the lower end of the rotary diverter 4 for lifting the fluid in the return line 11.
According to the present invention, in order to ensure that the low density drilling fluid fed into the choke line 13 through the additional injection line 14 can be sufficiently mixed with the original high density drilling fluid in the choke line 13 to ensure the precision of the dual gradient kill. Preferably, an additional injection line 14 communicates with the throttle line 13 at the lower end of the throttle line 13. That is, the additional injection line 14 may be connected to the end of the throttle line 13 connected to the second annulus 19.
According to the invention, a pump 16 can be provided at the upper opening of the additional injection line 14. The pump 16 is used to pump fluid into the additional injection line 14 so that the fluid flowing into the additional injection line 14 is more rapid and smooth, thereby improving the efficiency of the kill operation.
A flow regulator 20 is provided at the upper end of the choke line 13 for regulating the flow through the choke line 13 to control and regulate the riser pressure and the casing pressure. Preferably, the flow regulator 20 is a throttle valve.
The system 100 also includes a pressure boosting device (not shown). During deep water drilling, the pressurization device can deliver fluid into the first annulus 18 to pressurize. To reduce the number of lines of the system 100, the additional injection line 14 may be used as a booster line in selective communication with the first annulus 18. By the arrangement mode, the number of the pipelines of the system 100 is reduced, the construction difficulty is reduced, and the drilling operation cost is saved. It will be appreciated that valves 21 are provided between the additional injection line 14 and the first annulus 18, and between the additional injection line 14 and the choke line 13, for controlling the selective communication and blocking of the additional injection line 14 with the first annulus 18 and the choke line 13.
As shown in fig. 1, the system 100 also includes a kill line 10. Kill line 10 communicates with second annulus 19. When the well is closed in an empty state or the cut drill pipe 3 is closed, drilling fluid for killing can be conveyed into the well bore 6 through the killing pipeline 10.
The system 100 further comprises a remote control 17 and a control line 9. During operation of the system 100, the remote control device 17 may control subsea components such as the blowout preventer 5 and the rotary diverter 4 via the control line 9. It should be noted that the remote control device 17 may adopt electric control, hydraulic control, electrohydraulic control, acoustic control, underwater robot control, and the like. The system 100 also includes monitoring devices, such as pressure monitoring devices. These means can be selected by those skilled in the art according to actual needs and will not be described herein.
The method for implementing killing in deepwater dual-gradient drilling is described in detail below with reference to fig. 1:
firstly, before drilling operation, enough low-density drilling fluid needs to be reserved, and the density of the low-density drilling fluid is rholm. And, during drilling operations, the throttle line 13 is filled with a density pwThe sea water of (1).
Thirdly, after the overflow happens, the blowout preventer 5 is operated to shut in the well, and the well shut-in casing pressure P is obtained through the pressure monitoring devicea1(annular pressure at the top of the casing when shut-in) and shut-in vertical pressure Psp(internal pressure at the top of the drill pipe at shut-in) and calculate the required equivalent kill fluid density ρkeAnd actual kill fluid density ρk；
According to rhom(Hw+Hb)+Psp＝ρke(Hw+Hb)
Obtaining the equivalent weight of the well killing fluid
Then according to rhoke(Hw+Hb)＝ρkHb+ρwHw
Obtaining the actual well killing fluid density
Where ρ ismAs the density of the original drilling fluid, HwThe operating water depth; hbFor the depth at which the overflow occurs (measured downwards from the subsea location), ρwIs the density of seawater.
Next, cycle first week: the drilling mud pump 15 is started to kill the wellk(1/3-1/2 of normal drilling displacement in general) and pumping raw drilling fluid (with density rho) into the well bore 6 through the drill pipe 3m) (ii) a Simultaneously opening the additional injection line 14 and the pump 16 on the throttle line 13 to discharge the volume Qlm1A low density drilling fluid (density p) is pumped into the choke line 13lm) The low-density drilling fluid is mixed with the drilling fluid returned from the shaft 6 and then returns upwards (the density of the mixed drilling fluid is rho)x1) (ii) a While the first cycle is being cycled, the choke 20 is adjusted to maintain the riser pressure (internal pressure at the top of the drill pipe) constant (equal to the initial cycle pressure P)spci)，
According to rhoke(Hw+Hb)＝ρmHb+ρx1Hw
Obtaining the density of the mixed drilling fluid
Then according to
Obtaining the required discharge capacity of the low-density drilling fluid
The calculation formula of the initial circulating vertical pressure is Pspci＝Psp+ΔPci
Wherein, Δ PciThe circulating pressure loss of the original drilling fluid under the well killing discharge capacity is realized.
While circulating for the first week, according to the actual well killing fluid density rhokAnd (4) preparing the well killing fluid. After the first circulation is finished, closing the well and casing pressure Pa2Should equal shut-in vertical pressure Psp。
Again, cycle second week: the drilling mud pump 15 is started to kill the wellkA kill fluid (density ρ) is pumped through the drill pipe 3 into the wellbore 6k) Simultaneously opening the additional injection line 14 and the pump 16 on the choke line 13 to discharge the volume Qlm1A low density drilling fluid (density p) is pumped into the choke line 13lm) The low-density drilling fluid and the drilling fluid returned from the shaft are mixed and then return upwards (the density of the mixed drilling fluid is rho)x2) While the throttle valve 20 is adjusted to maintain the casing pressure (annulus pressure at the top of the casing) constant until the kill fluid reaches the bit; then slowly increasing the displacement of pump 16 until Qlm2The low density drilling fluid (density p) continues to be pumped into the choke line 13lm) While the choke 20 is adjusted to maintain the riser pressure (internal pressure at the top end of the drill pipe) constant (equal to the final circulating riser pressure P)spcf) Until the kill fluid is returned to the choke line 13. Wherein,
according to
Obtaining the required discharge capacity of the low-density drilling fluid
The calculation formula of the final circulating vertical pressure is
Finally, after the well killing is finished, the well is normally drilled in a double-gradient drilling mode, and the drilling fluid, the killing fluid and the low-density drilling fluid mixed fluid in the throttling pipeline 13 are replaced by seawater again through the pump 16 and the additional injection pipeline 14.
In the present application, the directional terms "upper", "lower", etc. are used with reference to the actual operating position of the system 100. In the present application, terms such as "low density" and "high density" merely indicate a relative relationship between the magnitudes of the densities. The depth of "deep water" in this application is not less than 500 meters.
The above description is only a preferred embodiment of the present invention, but the scope of the present invention is not limited thereto, and any person skilled in the art can easily make changes or variations within the technical scope of the present invention disclosed, and such changes or variations should be covered within the scope of the present invention. Therefore, the protection scope of the present invention shall be subject to the protection scope of the claims.
Claims (9)
1. A method of performing kill using a system for performing kill in deep water dual gradient drilling, the system comprising:
the drilling platform is provided with a drilling platform,
a riser extending downwardly from the rig,
a rotary flow divider, the top of which is connected with the riser,
a blowout preventer connected to a bottom of the rotary diverter, the blowout preventer being disposed at a subsea wellhead,
a drill pipe extending downwardly from the drilling platform, the drill pipe extending downwardly through the riser, the rotary flow diverter, and the blowout preventer in that order, and the drill pipe forming a first annulus with the riser and a second annulus with the wellbore,
a return line extending downwardly from the drilling platform, the return line communicable with the rotary diverter,
a choke line extending downwardly from the drilling platform, the choke line communicable with the second annulus,
an additional injection line extending downwardly from the drilling platform, the additional injection line communicable with the choke line;
the method comprises the following steps:
1) when the overflow happens, the blowout preventer is operated to shut in the well, and the well shut-in casing pressure P is obtaineda1And shut-in vertical pressure PspAnd calculating the required equivalent weight well killing fluid density rhokeAnd actual kill fluid density ρk，
Equivalent weight kill fluid density
Obtaining the actual well killing fluid density
Where ρ ismAs the density of the original drilling fluid, HwTo the depth of the operating water, HbMeasured downwards from the subsea location for the depth at which the overflow occurs, pwIs the density of seawater;
2) circulating for the first circle to kill the wellkFeeding the original drilling fluid into the wellbore through the drill pipe, and simultaneously opening the additional injection line to discharge a volume Qlm1Feeding the throttling pipeline with the density of rholmThe low-density drilling fluid enables the low-density drilling fluid to be mixed with the drilling fluid returned from the shaft and then return upwards, and the density of the mixed drilling fluid is rhox1During this process, the riser pressure is kept constant and equal to the initial cycle riser pressure Pspci，
Low densityRequired discharge capacity of drilling fluid
Density of mixed drilling fluid
The calculation formula of the initial circulating vertical pressure is Pspci＝Psp+ΔPci，
Wherein Q isk1/3-1/2 of normal drilling displacement, delta PciThe circulating pressure loss of the original drilling fluid under the well killing discharge capacity is realized;
3) circulating for the second week to kill the wellkFeeding a density p into the wellbore through the drill pipekOf the additional injection line is opened to discharge Qlm1Feeding the mixture with a density of rho into a throttling pipelinelmThe low-density drilling fluid enables the low-density drilling fluid to be mixed with the drilling fluid returned from the shaft and then return upwards, and the density of the mixed drilling fluid is rhox2Maintaining casing pressure until the kill fluid reaches the bit, and then increasing displacement until Qlm2Continuously feeding the throttling pipeline with the density of rholmWhile maintaining the riser pressure constant and equal to the final circulating vertical pressure PspcfUntil the well killing fluid returns to the throttling pipeline,
required discharge capacity of low-density drilling fluid
The calculation formula of the final circulating vertical pressure is
2. Method according to claim 1, characterized in that between steps 2) and 3) the actual kill fluid density p is followedkAnd (4) preparing the well killing fluid.
3. The method of claim 2, wherein the choke line is filled with a density p during drilling prior to step 1)wAnd after step 3) filling the choke line with seawater via the additional injection line.
4. The method of claim 1, wherein the additional injection line is communicable with the choke line at a lower end of the choke line.
5. A method according to claim 1 or 4, characterized in that a flow regulator for regulating the flow through the throttle line is arranged at the upper end of the throttle line.
6. Method according to claim 1 or 4, characterized in that a pump is provided at the upper opening of the additional injection line.
7. The method of claim 1 or 4, wherein the additional injection line is selectively communicable with the first annulus.
8. The method of claim 1 or 4, further comprising a kill line communicable with the second annulus, the kill line configured to deliver drilling fluid for killing into the wellbore when the well is shut-in empty or when the drill pipe is sheared off.
9. The method of claim 1 or 4, further comprising a control assembly capable of controlling the blowout preventer and the rotary diverter.
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| CN109538122B (en) * | 2018-12-29 | 2024-05-24 | 中国石油大学(北京) | Deep underwater catheter device and system |
| CN110617052B (en) * | 2019-10-12 | 2022-05-13 | 西南石油大学 | Device for controlling pressure of double-gradient drilling through air inflation of marine riser |
| CN110700775B (en) * | 2019-10-12 | 2021-11-02 | 西南石油大学 | Double-gradient drilling experiment bench for air inflation of marine riser in consideration of dynamic effect of drill rod |
| CN112878904B (en) * | 2021-01-25 | 2022-04-29 | 西南石油大学 | Well body structure optimization method of double-pipe double-gradient drilling technology |
| CN113250617A (en) * | 2021-06-28 | 2021-08-13 | 中国石油大学(北京) | Multi-gradient pressure control drilling system |
| US12044106B2 (en) | 2022-03-17 | 2024-07-23 | China University Of Petroleum-Beijing | Deep-water drilling gas kick pilot-scale apparatus |
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| CA2867387C (en) * | 2006-11-07 | 2016-01-05 | Charles R. Orbell | Method of drilling with a string sealed in a riser and injecting fluid into a return line |
| BRPI0812880A2 (en) * | 2007-06-01 | 2014-12-09 | Agr Deepwater Dev Systems Inc | SYSTEM AND METHOD FOR LIFTING A WELL HOLE DRILLING FLUID IN A TRAINING, PITCHING LIFTING RETURN FLUID SYSTEM IN A TRAINING, METHOD FOR CONTROLING A WELL HOLE IN A FORMATION |
| US8632318B2 (en) * | 2009-12-02 | 2014-01-21 | Vetco Gray Inc. | Pumping mud by electrohydrodynamic propulsion |
| US8434558B2 (en) * | 2010-11-15 | 2013-05-07 | Baker Hughes Incorporated | System and method for containing borehole fluid |
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