CN111980670B - Method for calculating well bottom sand setting amount in marine natural gas hydrate drilling and production process - Google Patents

Method for calculating well bottom sand setting amount in marine natural gas hydrate drilling and production process Download PDF

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CN111980670B
CN111980670B CN202011054871.3A CN202011054871A CN111980670B CN 111980670 B CN111980670 B CN 111980670B CN 202011054871 A CN202011054871 A CN 202011054871A CN 111980670 B CN111980670 B CN 111980670B
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natural gas
calculating
gas hydrate
drilling
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CN111980670A (en
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魏纳
张超
赵金洲
张烈辉
周守为
李清平
朱军龙
王晓然
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Southwest Petroleum University
China National Offshore Oil Corp CNOOC
CNOOC Research Institute Co Ltd
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China National Offshore Oil Corp CNOOC
CNOOC Research Institute Co Ltd
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06F—ELECTRIC DIGITAL DATA PROCESSING
    • G06F17/00—Digital computing or data processing equipment or methods, specially adapted for specific functions
    • G06F17/10—Complex mathematical operations

Abstract

The invention relates to a method for calculating the well bottom sand setting amount in the drilling and production process of marine natural gas hydrate, which comprises the following steps: acquiring wellhead monitoring parameters and stratum parameters in the marine natural gas hydrate jet flow fragmentation drilling and production process; step two, calculating the solid equivalent volume flow Q of the volume flow of the natural gas returned from the annular wellheadhyd1(t); step three, calculating the solid equivalent volume flow Q of the natural gas completely decomposed by the hydrate particles returned from the annular wellheadhyd2(t); step four, calculating the solid equivalent volume flow Q of the natural gas hydrate in the drilling and production processhyd(t); step five, calculating the volume rate Q of the silt entering the annular space of the well casings(t); step six, calculating the bottom sand setting rate Qss(t); step seven, calculating the volume V of the settled sand at the bottom of the wellssAnd (t) the bottom hole sand setting amount of the specified exploitation time is obtained. The method can conveniently calculate the bottom hole sand setting amount of the marine natural gas hydrate layer in the jet flow fragmentation process under the on-site construction condition, provides a basis for safe drilling construction, and avoids safety accidents.

Description

Method for calculating well bottom sand setting amount in marine natural gas hydrate drilling and production process
Technical Field
The invention belongs to the technical field of drilling and production of marine natural gas hydrates, and particularly relates to a method for calculating the sand setting amount of a well bottom in the drilling and production process of marine natural gas hydrates.
Background
The natural gas hydrate is a cage crystal compound which stably exists under low-temperature and high-pressure environmental conditions, and is commonly called as combustible ice. As a new type of clean energy, it is considered as the most potential alternative energy of the 21 st century. The natural gas hydrate storage tank has the remarkable characteristics of high gas storage density, high heat value, wide distribution range and the like, is mainly distributed in low-temperature and high-pressure environments of land permafrost zones and oceans at the periphery of land margins, and the amount of marine natural gas hydrate resources is about more than 100 times of that of the land permafrost zones. Aiming at the development of marine natural gas hydrate, the jet flow fragmentation drilling and production technology utilizes the condition that the temperature and the pressure of the hydrate are relatively stable at the seabed, a hydraulic jet flow nozzle is adopted to fragment the hydrate sediment into fine particles, solid phases such as hydrate particles and sand enter a shaft annulus along with jet flow fluid and return upwards, so that the natural gas is divided into two parts to be collected, one part of the hydrate particles are decomposed into natural gas and water in the shaft annulus along with the temperature rise and the pressure drop in the annulus, the other part of the undecomposed hydrate is completely decomposed into the natural gas and the water after returning to a sea surface platform, and finally the natural gas returned from the annulus and decomposed on the sea surface platform is collected. In the process, part of the mud and sand returns out of the annular wellhead along with the fluid, and part of the mud and sand is left in the shaft and gradually accumulated at the bottom of the shaft.
At present, the research at home and abroad aiming at ocean natural gas hydrate jet flow fragmentation drilling and production mainly aims at hydrate jet flow fragmentation construction method and parameter optimization, and less shaft bottom sand setting problem is involved in the process. Patent CN201710820737.1 discloses a mechanical jet combined mining method and device for non-diagenetic natural gas hydrate in a shallow seabed layer, which mainly relate to steps and devices of the mechanical jet combined mining method, and do not consider a specific solving method of bottom hole sand setting. The method is characterized in that a scholars (Zhou Jongji, Zhao jin Zhou, Liqing and the like, global first marine natural gas hydrate solid-state fluidization pilot production engineering parameter optimization design [ J ] natural gas industry, 2017, volume 37 (9):1-14) optimizes global first marine hydrate pilot production engineering parameters based on complex shaft multi-phase flow analysis in a marine hydrate jet flow fragmentation drilling and production process, establishes complex medium shaft multi-phase flow, temperature, pressure and hydrate phase balance, a decomposition theoretical model and a numerical value calculation method, and forms a marine hydrate fluidization pilot production site engineering parameter optimization design method and a pilot production scheme. But it also does not relate to the calculation of the sand setting amount at the bottom of the well during the ocean natural gas hydrate jet flow fragmentation drilling and production process.
In the process of jet flow fragmentation drilling and production of the natural gas hydrate, if part of hydrate sediments do not return out along with jet flow fluid along the annular space of a shaft, the sediments are gradually accumulated at the bottom of the shaft, so that bottom-hole sand setting is formed, the jet flow fragmentation effect can be influenced by the mass deposition of mud sand, the recovery ratio of the natural gas hydrate is reduced, even serious accidents such as the jet flow drilling tool is blocked and buried are caused, and the production is influenced and even the production is stopped. Therefore, a method for calculating the sand setting amount at the bottom of the well in the drilling and production process of the marine natural gas hydrate is urgently needed at present, and important guarantee is provided for safe and efficient construction of jet flow fragmentation drilling and production of the marine natural gas hydrate.
Disclosure of Invention
The invention aims to provide a method for calculating the bottom sand setting in the drilling and production process of marine natural gas hydrate, which has reliable principle, can quickly and accurately calculate the bottom sand setting in the jet flow fragmentation process through related known parameters and monitoring parameters, and has important significance for predicting the bottom sand setting condition and further ensuring the production efficiency and the construction safety.
In order to achieve the technical purpose, the invention adopts the following technical scheme.
A method for calculating the sand setting amount of a well bottom in the drilling and production process of an ocean natural gas hydrate sequentially comprises the following steps:
the method comprises the following steps of firstly, obtaining wellhead monitoring parameters and stratum parameters in the marine natural gas hydrate jet flow fragmentation drilling and production process, wherein the wellhead monitoring parameters comprise: volume flow Q of natural gas returned from annular wellheadg1(t) volume flow Q of natural gas fully decomposed from solid hydrate particles returned from annulus wellheadg2(t) volume flow Q of mud and sand returned from the annular wellheadsr(t); the formation parameters include: the porosity phi of the reservoir and the volume coefficient eta of the natural gas hydrate in the pores;
step two, calculating the solid equivalent volume flow Q of the volume flow of the natural gas (the natural gas obtained by decomposing the hydrate particles in the annulus) returned from the annulus wellhead by the following formulahyd1(t) (unit is m)3/s)：
Figure BDA0002704995040000021
Wherein B ishydBeing the volume factor of natural gas hydrate decomposition, B is a solid natural gas hydrate per unit volume that can decompose to release about 164 units volume of methanehydA general value of 164;
calculating the solid equivalent volume flow Q of the natural gas (the natural gas obtained by decomposing the hydrate particles on the sea surface platform) completely decomposed from the hydrate particles returned from the annular wellhead by the following formulahyd2(t) (unit is m)3/s)：
Figure BDA0002704995040000022
Step four, calculating the solid equivalent volume flow (the volume flow of solid natural gas hydrate contained in the annular space entering the well casing) Q of the natural gas hydrate in the drilling and production process by the following formulahyd(t) (unit is m)3/s)：
Qhyd(t)＝Qhyd1(t)+Qhyd2(t)；
Step five, calculating the volume rate Q of the silt entering the annular space of the well casing through the following formulas(t) (unit is m)3/s)：
Figure BDA0002704995040000023
Wherein
Figure BDA0002704995040000024
The volume rate of the hydrate ore body is drilled and mined, and the (1-phi) is the sediment content of the reservoir;
step six, calculating the bottom sand setting rate Qss(t) (unit is m)3S) are as follows:
Qss(t)＝Qs(t)-Qsr(t)；
step seven, calculating the volume V of the settled sand at the bottom of the wellss(t) (unit is m)3) The following were used:
Figure BDA0002704995040000031
namely the bottom hole sand setting amount of the appointed exploitation time.
Compared with the prior art, the invention has the following remarkable advantages:
(1) the method can conveniently and effectively realize the calculation of the sand setting amount at the bottom of the drilling well of the marine natural gas hydrate layer in the jet flow fragmentation process under the condition of field construction;
(2) providing a basis for safe drilling construction, and avoiding safety accidents;
(3) reliable data can be provided for subsequent scheme design in time;
(4) the invention has reliable principle and convenient operation, and is suitable for wide popularization and application.
Drawings
FIG. 1 is a diagram of the relationship between the bottom hole sand setting rate and the production time in the marine natural gas hydrate jet flow fragmentation drilling process.
FIG. 2 is a diagram of the relationship between the bottom hole sand setting volume and the production time in the marine natural gas hydrate jet flow fragmentation drilling process.
Detailed Description
The invention is further explained in detail by taking the calculation of the bottom sand setting of the actual ocean natural gas hydrate jet flow fragmentation drilling and production well in a certain area as an example and combining the attached drawings.
Example 1
In step one, a set of data is taken as an example. The volume coefficient B of natural gas hydrate decomposition is knownhyd164 volume flow rate Q of natural gas returning from the annulus wellheadg1(t)＝0.4445m3(s) natural gas equivalent volume flow Q completely decomposed from solid hydrate particles returned from annular wellheadg2(t)＝0.323m3(s) volume flow Q of mud and sand returned from annular wellheadsr(t)＝0.00705m3S; the porosity phi of the reservoir is 0.3, and the volume coefficient eta of the natural gas hydrate in the pores is 0.8;
step two, calculating the solid equivalent volume flow of the decomposed natural gas hydrate in the annular space:
Figure BDA0002704995040000032
step three, calculating the solid equivalent volume flow of the natural gas hydrate returned from the annular wellhead:
Figure BDA0002704995040000033
step four, calculating the volume rate of the solid-phase natural gas hydrate contained in the annular space entering the well casing: qhyd(t)＝Qhyd1(t)+Qhyd2(t)＝0.00467987804m3/s；
Step five, calculating the volume rate of the silt entering the annular space of the well casing:
Figure BDA0002704995040000041
Figure BDA0002704995040000042
step six, calculating the bottom hole sand setting rate: qss(t)＝Qs(t)-Qsr(t)＝0.00659964429m3/s；
Step seven, calculating the volume of the settled sand at the bottom of the well:
Figure BDA0002704995040000043
this is the amount of sand settled at the bottom of the well per unit time.
Example 2
Taking partial working condition data as an example, the volume coefficient B of natural gas hydrate decomposition is knownhyd164. The reservoir porosity phi is 0.3, and the volume coefficient eta of the natural gas hydrate in the pores is 0.8. Some of the operating conditions are shown in table 1.
Table 1 partial Condition data and results
Time/s Qg1(t)m3/s Qg2(t)m3/s Qsr(t)m3/s Qss(t)m3/s Vss(t)/m 3
0 0 0 0 0 0
1 0.4445 0.323 0.00705 0.0066 0.00705
2 0.476 0.32015 0.00711 0.007049 0.01416
3 0.441 0.32015 0.00735 0.006187 0.02151
4 0.483 0.32015 0.00771 0.006574 0.02922
By applying the calculation method of the invention, the relationship between the bottom hole sand setting rate and the exploitation time is shown in figure 1, the relationship between the bottom hole sand setting volume and the exploitation time is shown in figure 2, and the bottom hole sand setting volume is increased along with the increase of the exploitation time.

Claims (3)

1. A method for calculating the sand setting amount of a well bottom in the drilling and production process of an ocean natural gas hydrate sequentially comprises the following steps:
the method comprises the following steps of firstly, obtaining wellhead monitoring parameters and stratum parameters in the marine natural gas hydrate jet flow fragmentation drilling and production process, wherein the wellhead monitoring parameters comprise: volume flow Q of natural gas returned from annular wellheadg1(t) volume flow Q of natural gas fully decomposed from solid hydrate particles returned from annulus wellheadg2(t) volume flow Q of mud and sand returned from the annular wellheadsr(t); the formation parameters include: the porosity phi of the reservoir and the volume coefficient eta of the natural gas hydrate in the pores;
step two, calculating the solid equivalent volume flow Q of the volume flow of the natural gas returned from the annular wellhead by the following formulahyd1(t)：
Figure FDA0003509268830000011
Wherein B ishydIs the volume coefficient of natural gas hydrate decomposition;
step three, calculating the annulus by the following formulaSolid equivalent volume flow Q of natural gas completely decomposed from hydrate particles returned from wellheadhyd2(t)：
Figure FDA0003509268830000012
Step four, calculating the solid equivalent volume flow Q of the natural gas hydrate in the drilling and production process through the following formulahyd(t)：
Qhyd(t)＝Qhyd1(t)+Qhyd2(t)；
Step five, calculating the volume rate Q of the silt contained in the fluid entering the annular space of the well casing through the following formulas(t)：
Figure FDA0003509268830000013
Step six, calculating the bottom sand setting rate Qss(t) the following:
Qss(t)＝Qs(t)-Qsr(t)；
step seven, calculating the volume V of the settled sand at the bottom of the wellss(t) the following:
Figure FDA0003509268830000014
namely the bottom hole sand setting amount of the appointed exploitation time.
2. The method for calculating the amount of sand deposited at the bottom of the well during the drilling and production process of marine natural gas hydrate as claimed in claim 1, wherein in the second step, the solid natural gas hydrate per unit volume can be decomposed to release about 164 unit volumes of methane, BhydTaking the value of 164.
3. The method for calculating the amount of sand deposited at the bottom of the well during the drilling and production process of the marine natural gas hydrate as claimed in claim 1, wherein in the fifth step,
Figure FDA0003509268830000015
the volume rate of the hydrate ore body is drilled and mined, and the (1-phi) is the volume content of reservoir silt.
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