CN117846542A - Method and equipment for testing adaptability of water-based completion fluid in hydrogen sulfide-containing crude oil - Google Patents
Method and equipment for testing adaptability of water-based completion fluid in hydrogen sulfide-containing crude oil Download PDFInfo
- Publication number
- CN117846542A CN117846542A CN202211207530.4A CN202211207530A CN117846542A CN 117846542 A CN117846542 A CN 117846542A CN 202211207530 A CN202211207530 A CN 202211207530A CN 117846542 A CN117846542 A CN 117846542A
- Authority
- CN
- China
- Prior art keywords
- completion fluid
- hydrogen sulfide
- temperature
- pressure
- crude oil
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
- 239000012530 fluid Substances 0.000 title claims abstract description 273
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 title claims abstract description 228
- 229910000037 hydrogen sulfide Inorganic materials 0.000 title claims abstract description 227
- 239000010779 crude oil Substances 0.000 title claims abstract description 141
- 238000000034 method Methods 0.000 title claims abstract description 61
- 238000012360 testing method Methods 0.000 title claims abstract description 60
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 40
- 238000006243 chemical reaction Methods 0.000 claims abstract description 199
- 239000007789 gas Substances 0.000 claims abstract description 63
- 238000010438 heat treatment Methods 0.000 claims abstract description 37
- 230000035484 reaction time Effects 0.000 claims abstract description 14
- 229920006395 saturated elastomer Polymers 0.000 claims abstract description 12
- 238000005086 pumping Methods 0.000 claims abstract description 7
- 150000002978 peroxides Chemical class 0.000 claims abstract description 6
- 238000010998 test method Methods 0.000 claims abstract description 4
- 238000001514 detection method Methods 0.000 claims description 39
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims description 38
- 239000001569 carbon dioxide Substances 0.000 claims description 19
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 19
- 238000001556 precipitation Methods 0.000 claims description 19
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 claims description 12
- 238000002425 crystallisation Methods 0.000 claims description 11
- 230000008025 crystallization Effects 0.000 claims description 11
- 230000008859 change Effects 0.000 claims description 9
- 238000012216 screening Methods 0.000 claims description 8
- 125000000864 peroxy group Chemical group O(O*)* 0.000 claims description 5
- 230000015572 biosynthetic process Effects 0.000 claims description 4
- 238000001816 cooling Methods 0.000 claims description 3
- 238000007599 discharging Methods 0.000 claims description 3
- 238000011056 performance test Methods 0.000 claims description 3
- 230000001502 supplementing effect Effects 0.000 claims description 3
- 238000010521 absorption reaction Methods 0.000 claims description 2
- 150000002500 ions Chemical class 0.000 description 12
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 8
- 238000004364 calculation method Methods 0.000 description 7
- 238000002474 experimental method Methods 0.000 description 5
- 239000012071 phase Substances 0.000 description 5
- 238000002156 mixing Methods 0.000 description 4
- 239000000203 mixture Substances 0.000 description 4
- 238000012546 transfer Methods 0.000 description 4
- 230000005484 gravity Effects 0.000 description 3
- 239000003921 oil Substances 0.000 description 3
- 239000003208 petroleum Substances 0.000 description 3
- 230000008569 process Effects 0.000 description 3
- 230000036632 reaction speed Effects 0.000 description 3
- 230000009257 reactivity Effects 0.000 description 3
- 230000003068 static effect Effects 0.000 description 3
- 239000000126 substance Substances 0.000 description 3
- PTFCDOFLOPIGGS-UHFFFAOYSA-N Zinc dication Chemical compound [Zn+2] PTFCDOFLOPIGGS-UHFFFAOYSA-N 0.000 description 2
- 229910052799 carbon Inorganic materials 0.000 description 2
- 238000005336 cracking Methods 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 230000006872 improvement Effects 0.000 description 2
- 239000007791 liquid phase Substances 0.000 description 2
- 230000009467 reduction Effects 0.000 description 2
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 1
- BHPQYMZQTOCNFJ-UHFFFAOYSA-N Calcium cation Chemical compound [Ca+2] BHPQYMZQTOCNFJ-UHFFFAOYSA-N 0.000 description 1
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 1
- UCKMPCXJQFINFW-UHFFFAOYSA-N Sulphide Chemical compound [S-2] UCKMPCXJQFINFW-UHFFFAOYSA-N 0.000 description 1
- 229910001424 calcium ion Inorganic materials 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000013400 design of experiment Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 125000004435 hydrogen atom Chemical class [H]* 0.000 description 1
- QAOWNCQODCNURD-UHFFFAOYSA-M hydrogensulfate Chemical compound OS([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-M 0.000 description 1
- 229910052751 metal Inorganic materials 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 150000002739 metals Chemical class 0.000 description 1
- JCXJVPUVTGWSNB-UHFFFAOYSA-N nitrogen dioxide Inorganic materials O=[N]=O JCXJVPUVTGWSNB-UHFFFAOYSA-N 0.000 description 1
- 238000011017 operating method Methods 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 239000002244 precipitate Substances 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- 239000007858 starting material Substances 0.000 description 1
- 229910052717 sulfur Inorganic materials 0.000 description 1
- 239000011593 sulfur Substances 0.000 description 1
- 239000013589 supplement Substances 0.000 description 1
- 239000002341 toxic gas Substances 0.000 description 1
- 238000006276 transfer reaction 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
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
-
- 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
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- Health & Medical Sciences (AREA)
- Food Science & Technology (AREA)
- Medicinal Chemistry (AREA)
- Analytical Chemistry (AREA)
- Biochemistry (AREA)
- General Health & Medical Sciences (AREA)
- General Physics & Mathematics (AREA)
- Immunology (AREA)
- Pathology (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
The invention provides a method and equipment for testing the adaptability of a water-based completion fluid in crude oil containing hydrogen sulfide. The test method comprises the following steps: detecting a completion fluid to be detected; pumping the crude oil into a high-temperature high-pressure reaction kettle, and introducing hydrogen sulfide gas until the crude oil is saturated with hydrogen sulfide; introducing a completion fluid to be tested for removing peroxide into the reaction kettle; heating the reaction kettle to a set temperature and adjusting the temperature to a set pressure, wherein the set pressure is hydrogen sulfide loss; after the set reaction time is reached, releasing pressure and stopping heating; and comparing the changes of the completion fluid before and after the reaction to judge whether the completion fluid is suitable for the hydrogen sulfide-containing crude oil. The apparatus includes: the high-temperature high-pressure reaction kettle, a hydrogen sulfide tank, a completion fluid inlet pipeline, a gas discharge pipeline, a pressure measuring device and a temperature control device. The testing method provided by the invention can simulate the interface reaction between the completion fluid and the crude oil containing hydrogen sulfide in the stratum when the completion fluid is in a well control state, and accurately judge the adaptability of the water-based completion fluid in the crude oil containing hydrogen sulfide.
Description
Technical Field
The invention relates to a method and equipment for testing the adaptability of a water-based completion fluid in crude oil containing hydrogen sulfide, and belongs to the technical field of petroleum engineering.
Background
Many reservoir crudes contain hydrogen sulfide, so the working fluids used in completion must be considered for hydrogen sulfide resistance. In particular completion fluids, if reacted with hydrogen sulfide, on the one hand tend to produce precipitates that plug the wellbore or reservoir; more importantly, on the other hand, the completion fluid density may change, thereby presenting well control risks. Thus, completion fluids for hydrogen sulfide-containing oil and gas wells require hydrogen sulfide resistance testing to ensure their stability in a hydrogen sulfide-containing wellbore environment.
However, the design of experiments for the reaction of completion fluids with hydrogen sulfide containing crude oils has been a bottleneck in the industry. When the completion fluid stands in the well bore, the completion fluid mainly plays a role in well control. Its reaction with the hydrogen sulfide containing crude oil occurs only at the interface of completion fluid-crude oil contact. It is not reasonable to directly mix the completion fluid with the crude oil to react. Meanwhile, hydrogen sulfide is extremely toxic gas, and the mixing reaction is easy to cause leakage, so that the personal safety of experimental staff is endangered.
Currently, when evaluating the hydrogen sulfide resistance of completion fluids, two methods are generally used: one is to first prepare a dilute solution of hydrogen sulfide (i.e., hydrogen sulfate) and mix it with a completion fluid to test its hydrogen sulfide resistance; the other is to put a completion fluid into a high-temperature high-pressure reaction kettle, and then to introduce hydrogen sulfide gas into the completion fluid to test the hydrogen sulfide resistance. Neither method simulates the actual interface reaction state and does not simulate the actual concentration of hydrogen sulfide. Hydrogen sulfide resistance testing of completion fluids has long been one of the problems to be solved in the art.
Disclosure of Invention
In order to solve the technical problems, the invention aims to provide a method and equipment for testing the adaptability of a water-based completion fluid in crude oil containing hydrogen sulfide. The testing method provided by the invention can simulate the interface reaction between the completion fluid and the crude oil containing hydrogen sulfide in the stratum when the completion fluid is in a well control state, and accurately judge the adaptability of the water-based completion fluid in the crude oil containing hydrogen sulfide.
To achieve the above object, a first aspect of the present invention provides a method for testing the suitability of a water-based completion fluid in hydrogen sulfide-containing crude oil, comprising the steps of:
(1) Detecting a completion fluid to be detected, wherein the detection at least comprises detection of basic performance of the completion fluid to be detected, and the detection of basic performance of the completion fluid to be detected at least comprises density detection;
(2) Pumping the crude oil into a high-temperature high-pressure reaction kettle, and then introducing hydrogen sulfide gas into the high-temperature high-pressure reaction kettle for a period of time until the crude oil is saturated with hydrogen sulfide;
(3) Deoxidizing the completion fluid to be tested, and then introducing the completion fluid to be tested with the peroxy removed into a high-temperature high-pressure reaction kettle;
(4) Heating the high-temperature high-pressure reaction kettle to a set temperature, and adjusting the pressure to a set pressure, wherein the set pressure is the loss degree of the hydrogen sulfide, and then keeping the hydrogen sulfide stable; measuring the temperature and the pressure of the high-temperature high-pressure reaction kettle once at intervals, and if the temperature and/or the pressure are different from the set temperature and/or the set pressure, adjusting the temperature and/or the pressure of the high-temperature high-pressure reaction kettle to be the same as the set temperature and the set pressure;
(5) After the set reaction time is reached, the pressure is removed, the heating is stopped, the high-temperature high-pressure reaction kettle is cooled to the room temperature, and the fluid in the reaction kettle is discharged;
(6) Detecting a reacted completion fluid, the detecting comprising at least detecting a basic property of the reacted completion fluid, the detecting comprising at least density detecting;
(7) And (3) judging whether the completion fluid is suitable for the hydrogen sulfide-containing crude oil or not at least based on the detection result of the completion fluid to be detected obtained in the step (1) and the detection result of the completion fluid after reaction obtained in the step (6).
According to a specific embodiment of the present invention, preferably, the test method further comprises a preliminary screening after step (1), the preliminary screening comprising:
(a) Pumping the crude oil into a high-temperature high-pressure reaction kettle, and then introducing hydrogen sulfide gas into the high-temperature high-pressure reaction kettle for a period of time until crude oil is saturated with hydrogen sulfide;
(a) -2, deoxidizing the completion fluid to be tested, and then introducing the completion fluid to be tested with the peroxide removed into a high-temperature high-pressure reaction kettle;
(a) 3, heating the high-temperature high-pressure reaction kettle to a set temperature, adjusting the pressure to normal pressure to be used as a set pressure, and then keeping the pressure stable; measuring the temperature of the high-temperature high-pressure reaction kettle once at intervals, and if the temperature is different from the set temperature, adjusting the temperature of the high-temperature high-pressure reaction kettle to be the same as the set temperature;
(a) After the set reaction time is reached, stopping heating, cooling the high-temperature high-pressure reaction kettle to room temperature, and discharging the fluid in the reaction kettle;
(a) -5 detecting a reacted completion fluid, the detecting comprising at least a detection of a basic property of the reacted completion fluid, the detection of a basic property of the reacted completion fluid comprising at least a density detection;
(a) -6, based at least on the detection result of the completion fluid to be tested and the detection result of the completion fluid after reaction, preliminarily judging whether the completion fluid is suitable for hydrogen sulfide-containing crude oil, and performing steps (2) to (7) on the completion fluid with the preliminary judgment result being suitable for hydrogen sulfide-containing crude oil, so as to finally judge whether the completion fluid is suitable for hydrogen sulfide-containing crude oil.
It will be appreciated by those skilled in the art that since step (1) above has performed basic performance testing on the completion fluid to be tested, it may not be necessary to repeat the basic performance testing on the completion fluid to be tested during the preliminary screening process.
In the above method, preferably, in step (1), the basic performance detection of the completion fluid to be tested further includes one or a combination of several of pH detection, viscosity detection, crystallization temperature detection, turbidity detection, and the like.
In the above method, preferably, in step (1), the detection of the completion fluid to be tested further includes detecting an ion content of the completion fluid to be tested.
In the above method, it is preferable that the amount of crude oil pumped into the high temperature and high pressure reaction vessel in step (2) and step (a) -1 is 1000 to 3000mL.
In the above method, preferably, in the step (2) and the step (a) -1, the hydrogen sulfide gas is introduced for 1.5 to 2.5 hours, so that the crude oil is saturated with hydrogen sulfide, that is, the crude oil is dissolved as much hydrogen sulfide as possible, while the influence of other residual gases in the reaction vessel is maximally removed.
In the above method, preferably, step (2) and step (a) -1 further comprise: introducing carbon dioxide gas into the high-temperature high-pressure reaction kettle for a period of time until crude oil is saturated with hydrogen sulfide and carbon dioxide. The time for introducing the hydrogen sulfide gas and the carbon dioxide gas may be 1.5 to 2.5 hours.
In the above method, in step (3) and step (a) -2, the method of deoxidizing the completion fluid to be tested may adopt a conventional method of deoxidizing the completion fluid in the field, and preferably, the method of deoxidizing may be activated carbon deoxidization. The specific operating method for deoxidizing the activated carbon and the dosage proportion of the activated carbon to the completion fluid to be tested can be adjusted conventionally by a person skilled in the art.
In the above method, it is preferable that the amount of the completion fluid to be measured for removing the peroxide introduced into the high temperature and high pressure reaction vessel in the step (3) and the step (a) -2 is 1000 to 3000mL.
In the above method, preferably, the amount of crude oil pumped into the high temperature and high pressure reaction vessel is the same as the amount of the completion fluid to be tested for removing peroxy gas introduced into the high temperature and high pressure reaction vessel.
In the above method, preferably, in step (4), the fugacity of hydrogen sulfide is calculated according to the following formula (1):
in the formula (1),the loss of hydrogen sulfide is expressed in MPa; />The unit is MPa, which is the partial pressure of hydrogen sulfide;is the fugacity coefficient.
Where the partial pressure of hydrogen sulfide is the partial pressure of hydrogen sulfide in the hydrogen sulfide-containing crude oil, the specific calculation is conventional in the art and is generally obtained by multiplying the total system pressure (i.e., the formation pressure of the hydrogen sulfide-containing crude oil) by the mole fraction of hydrogen sulfide in the gas phase. Coefficient of fugacity The calculation may also be performed by a method conventional in the art, for example, according to the fugacity coefficient calculation formula for the components in the mixture obtained by combining the SRK equation with the 1 parameter van der Waals mixing rule disclosed in pages 6 to 8 of the book "improvement of SRK equation and its application in phase equilibrium calculation" (romming, university of Tianjin's university, university of s paper, 12 2005), that is, the formula (2-34).
In the above method, preferably, in step (4) and step (a) -3, the set temperature is the crude oil temperature of the working formation of the completion fluid to be tested, and more preferably may be 80 to 120 ℃.
In the above method, it is preferable that in the step (4), the temperature and pressure of the high-temperature high-pressure reaction vessel are measured every 60 to 80 hours.
In the above method, it is preferable that in step (a) -3, the temperature of the high-temperature high-pressure reaction vessel is measured every 24 to 80 hours. More preferably, the temperature of the high-temperature high-pressure reaction vessel is measured every 60 to 80 hours.
In the above method, preferably, in the step (4), the temperature of the high-temperature high-pressure reaction vessel is adjusted by the intensity of heating, and the pressure of the high-temperature high-pressure reaction vessel is adjusted by introducing hydrogen sulfide gas. More preferably, when the measured pressure of the high-temperature high-pressure reaction kettle is lower than the set pressure by more than 0.5MPa, the pressure is supplemented to the set pressure by introducing hydrogen sulfide gas into the high-temperature high-pressure reaction kettle. More preferably, the flow rate of the hydrogen sulfide gas is 10mm/min or less and the flow rate is 150 to 250mL/min (particularly preferably 200 mL/min) when the pressure is adjusted. Alternatively, if step (2) further comprises: introducing carbon dioxide gas into the high-temperature high-pressure reaction kettle for a period of time until crude oil is saturated with hydrogen sulfide and carbon dioxide, and adjusting the pressure of the high-temperature high-pressure reaction kettle by introducing the hydrogen sulfide gas and the carbon dioxide gas, wherein the flow rates of the hydrogen sulfide gas and the carbon dioxide gas are preferably less than 10mm/min and 150-250 mL/min (more preferably 200 mL/min). When the pressure is supplemented, the flow velocity and the flow rate of the gas defined by the method can avoid disturbance and flow impact at the outlet of the gas in the reaction kettle, and further avoid convection on the interface of crude oil and completion fluid.
In the above method, preferably, in step (a) -3, the temperature of the high-temperature high-pressure reaction vessel is adjusted by the intensity of heating.
In the above method, preferably, in step (5), the set reaction time is 6 to 8 days.
In the above method, preferably, in step (a) -4, the set reaction time is 1 day to 2 months. More preferably, the set reaction time is 1 month to 2 months.
In the above method, preferably, in step (6) and steps (a) -5, the basic performance test of the completion fluid after the reaction further includes one or a combination of several of pH value test, viscosity test, crystallization temperature test, turbidity test, and the like.
In the above method, preferably, in step (6) and steps (a) -5, the detecting of the completion fluid after the reaction further comprises detecting an ion content of the completion fluid after the reaction.
In the above method, preferably, in step (7), determining whether the completion fluid is suitable for use with hydrogen sulfide-containing crude oil includes the following means: if the density of the completion fluid before and after the reaction varies by more than 0.2SG or if there is significant precipitation of the completion fluid after the reaction, the completion fluid is not suitable for hydrogen sulfide containing crude oil. More preferably, the significant precipitation is a 300-400 mesh (more preferably 400 mesh) screen after precipitation in an amount of 100g/1000mL (post-reaction completion fluid amount) or more. Wherein SG (specific gravity) is the ratio of the density of the completion fluid to the density of water at 3.98 ℃ at standard atmospheric pressure.
In the above method, preferably, in step (7), determining whether the completion fluid is suitable for use with hydrogen sulfide-containing crude oil further comprises the following means: if the pH value of the completion fluid to be tested is 2 or more, or if the viscosity of the completion fluid before and after the reaction varies by 10mPa.s or more, or if the crystallization temperature of the completion fluid before and after the reaction varies by 5 ℃ or more, or if the turbidity of the completion fluid before and after the reaction varies by 10NTU or more, the completion fluid is not suitable for hydrogen sulfide-containing crude oil.
In the above method, preferably, in step (7), determining whether the completion fluid is suitable for use with hydrogen sulfide-containing crude oil further comprises the following means: if the primary ion content of the completion fluid before and after the reaction varies by 0.05kg/L or more, the completion fluid is not suitable for hydrogen sulfide-containing crude oil. Wherein, the main ions comprise calcium ions, zinc ions and the like, and are mainly derived from inorganic salts and the like conventionally used in completion fluids.
In the above method, in the step (7), if the density of the completion fluid before and after the reaction is changed to 0.2SG or less and there is no significant precipitation of the completion fluid after the reaction, and if the pH, viscosity, crystallization temperature, turbidity, and ion content of the completion fluid before and after the reaction are also detected, the above index conditions for the completion fluid unsuitable for hydrogen sulfide-containing crude oil are not satisfied, and the completion fluid is suitable for hydrogen sulfide-containing crude oil.
In the above method, preferably, in step (a) -6, the preliminary determination of whether the completion fluid is suitable for use with hydrogen sulfide-containing crude oil includes the following means: if the density change of the completion fluid before and after the reaction is greater than 0.2SG or if there is significant precipitation of the completion fluid after the reaction, the completion fluid is not suitable for hydrogen sulfide containing crude oil; if the density change of the completion fluid before and after the reaction is below 0.2SG and no obvious precipitation exists in the completion fluid after the reaction, the completion fluid is primarily judged to be suitable for the hydrogen sulfide-containing crude oil. More preferably, the significant precipitation is a 300-400 mesh (more preferably 400 mesh) screen after precipitation in an amount of 100g/1000mL (post-reaction completion fluid amount) or more. And (3) performing the steps (2) to (7) on the completion fluid which is subjected to preliminary screening and is suitable for the hydrogen sulfide-containing crude oil, so as to finally judge whether the completion fluid is suitable for the hydrogen sulfide-containing crude oil.
In the above method, preferably, in step (a) -6, preliminarily judging whether the completion fluid is suitable for hydrogen sulfide-containing crude oil further comprises the following means: if the pH value of the completion fluid to be tested is 2 or more, or if the viscosity of the completion fluid before and after the reaction varies by 10mPa.s or more, or if the crystallization temperature of the completion fluid before and after the reaction varies by 5 ℃ or more, or if the turbidity of the completion fluid before and after the reaction varies by 10NTU or more, the completion fluid is not suitable for hydrogen sulfide-containing crude oil.
In the above method, preferably, in step (a) -6, preliminarily judging whether the completion fluid is suitable for hydrogen sulfide-containing crude oil further comprises the following means: if the primary ion content of the completion fluid before and after the reaction varies by 0.05kg/L or more, the completion fluid is not suitable for hydrogen sulfide-containing crude oil.
In the above method, in the steps (a) -6, if the pH, viscosity, crystallization temperature, turbidity, and ion content of the completion fluid before and after the reaction are also detected during the preliminary screening, the above index conditions of the completion fluid unsuitable for hydrogen sulfide-containing crude oil are not satisfied, and the completion fluid is preliminarily judged to be suitable for hydrogen sulfide-containing crude oil.
In the above method, preferably, the steps (a) -6 further include: steps (2) - (7) may also be performed on completion fluids that were not suitable for hydrogen sulfide-containing crude oil as a result of the preliminary determination to ultimately determine whether the completion fluid is suitable for hydrogen sulfide-containing crude oil.
The method for testing the adaptability of the water-based completion fluid in the hydrogen sulfide-containing crude oil is a method for testing the hydrogen sulfide resistance of the water-based completion fluid for oil and gas wells, can simulate the interface reaction between the completion fluid and the stratum hydrogen sulfide-containing crude oil when the completion fluid is in a well killing state, and accurately judges the adaptability of the water-based completion fluid in the hydrogen sulfide-containing crude oil. The method has at least the following initial progress:
(1) According to the invention, the experimental pressure condition is simulated by adopting the loss of hydrogen sulfide in crude oil under a specific temperature and pressure environment, so that the experimental pressure condition is more real and effective (the loss represents the effective pressure of actual gas in chemical thermodynamics); on the other hand, it is lower than the value of the partial pressure, is easier to achieve in a laboratory than using the partial pressure to simulate the experimental pressure, and has less experimental risk.
Experiments in the petroleum industry on hydrogen sulfide all assume that hydrogen sulfide is in a gaseous state, and the pressure of hydrogen sulfide is obtained by multiplying the total system pressure by the mole fraction of hydrogen sulfide in the gas phase. Industry standard NACE TM0177: l (L)aboratory Testing of Metals for Resistance to Sulfide Stress Cracking and Stress Corrosion Cracking in H 2 S Environments also recommend that the partial pressure of hydrogen sulfide in the gas be used to simulate a corrosive environment containing hydrogen sulfide-mixing hydrogen sulfide with nitrogen or carbon dioxide to achieve the desired partial pressure, and then introducing the mixed gas into the reaction solution.
In the reaction of hydrogen sulfide with completion fluid in the dissolved state according to the present invention, however, it is not reasonable to conduct the simulation experiment using partial pressure as described above, because the chemical reactivity of hydrogen sulfide is much lower than that in the gaseous state. If partial pressure is used to characterize, the reactivity of hydrogen sulfide is estimated to be too high (especially under high temperature and pressure conditions) to be practical; and if the pressure of the reaction environment is too high, it is difficult to simulate under laboratory conditions. The present invention creatively uses the fugacity to characterize the chemical reactivity of hydrogen sulfide in solution.
(2) The invention utilizes the density difference and gravity difference of the water-based completion fluid and crude oil to simulate the interface reaction of the completion fluid and the crude oil containing hydrogen sulfide. The crude oil is firstly placed in a reaction kettle, then hydrogen sulfide is introduced to saturation, and then completion fluid for removing peroxy is pumped into the reaction kettle, wherein the completion fluid is concentrated below the crude oil containing hydrogen sulfide because of high density, so that the hydrogen sulfide is ensured to react with the completion fluid only through mass transfer to a crude oil interface in the reaction process.
In the petroleum industry, when testing the reaction of hydrogen sulfide with well fluids, methods are often employed in which hydrogen sulfide gas is directly introduced into the liquid phase. But this is far from simulating the contact reaction of hydrogen sulfide containing crude oil with the well fluid. When the experiment of the invention is carried out by the method, the problem that the measured reaction speed is far higher than the actual reaction speed can be necessarily caused. This is because the reaction rate of hydrogen sulfide dissolved crude oil with completion fluid depends on two processes: the first is convection and the second is mass transfer. It is important how to simulate the reaction process of mass transfer control. In the application scene, the completion fluid and the crude oil are static, the hydrogen sulfide is also in a dissolved state and is in a static liquid phase, no convection occurs, and only mass transfer is affected on the reaction speed. The invention firstly saturates the crude oil with hydrogen sulfide, then makes contact reaction with the completion fluid under a standing state, and completely and truly simulates the working state of the completion fluid, which is an innovative progress in the industry.
In addition, in the present invention, the order of introduction of the respective fluids is also important. If the completion fluid is introduced first and then the crude oil is introduced, hydrogen sulfide cannot be saturated in the crude oil, and the completion fluid and the hydrogen sulfide cannot be guaranteed not to react in a convection manner. The method of the invention is that crude oil and saturated hydrogen sulfide are introduced first, and then completion fluid is introduced; and the static state is kept in the whole reaction process, and the mass transfer reaction of the interface is truly simulated.
(3) The invention ensures the constancy of experimental pressure conditions in the whole reaction process through pressure compensation. In the experimental reaction process, if the system pressure reduction value is detected to be larger than 0.5MPa, introducing hydrogen sulfide gas to carry out pressure compensation, and ensuring that the pressure value in the whole reaction process is equal to the set fugacity value.
In a second aspect, the present invention provides an apparatus for testing the suitability of a water-based completion fluid in a hydrogen sulfide containing crude oil, the apparatus being for implementing a method for testing the suitability of a water-based completion fluid as described above in a hydrogen sulfide containing crude oil, the apparatus comprising at least: the high-temperature high-pressure reaction kettle, the hydrogen sulfide tank, the completion fluid inlet pipeline, the gas discharge pipeline, the pressure measuring device and the temperature control device; the temperature control device comprises a heating unit, a temperature measuring unit and an adjusting unit;
Wherein the hydrogen sulfide tank is connected with the high-temperature high-pressure reaction kettle through a pipeline; the completion fluid inlet pipeline is connected to the high-temperature high-pressure reaction kettle; the gas exhaust pipeline is connected to the high-temperature high-pressure reaction kettle; the pressure measuring device is arranged on the gas discharge pipeline through a tee joint; the heating unit is arranged in the high-temperature high-pressure reaction kettle; the temperature measuring unit is connected to the high-temperature high-pressure reaction kettle; and after the temperature measured by the temperature measuring unit is collected by the adjusting unit, the heating intensity of the heating unit is controlled to realize the adjustment of the temperature of the high-temperature high-pressure reaction kettle.
In the above apparatus, preferably, a tank opening of the hydrogen sulfide tank is provided with a pressure reducing regulator.
In the above apparatus, preferably, a tank opening of the hydrogen sulfide tank is provided with a pressure compensating valve that controls a needle valve and a check valve. The pressure compensating valve is arranged at a position closer to the tank opening of the hydrogen sulfide tank than the needle valve. More preferably, the needle valve has a nominal diameter of 5mm. The pressure compensating valve adopted by the invention comprises a needle valve capable of precisely controlling flow and a check valve for preventing backflow. If the system pressure reduction value is detected to be larger than 0.5MPa, the check valve and the needle valve are opened to carry out pressure compensation, but the opening degree of the needle valve is lower so as to ensure that the flow speed of the hydrogen sulfide gas subjected to pressure compensation is lower, so that disturbance and flow impact at the outlet of the hydrogen sulfide gas in the reaction kettle are avoided, and convection on the interface of crude oil and completion fluid is further avoided. Thus, the present invention preferably employs a needle valve having a nominal diameter of 5mm.
According to a specific embodiment of the present invention, preferably, the apparatus for testing the adaptability of the water-based completion fluid in the hydrogen sulfide-containing crude oil further comprises a carbon dioxide tank connected to a pipeline connected to the high temperature and high pressure reaction vessel through a tee joint.
In the above apparatus, preferably, a pressure reducing regulator is provided at a tank opening of the carbon dioxide tank and the tank.
In the above apparatus, preferably, a tank opening of the carbon dioxide tank is provided with a check valve, and a needle valve is provided on a line in which the tee is connected to the high temperature and high pressure reaction tank. More preferably, the needle valve has a nominal diameter of 5mm.
According to a specific embodiment of the present invention, preferably, the apparatus for testing the adaptability of the water-based completion fluid in the crude oil containing hydrogen sulfide further comprises a hydrogen sulfide absorbing device, and one end of the gas discharge line is connected to the high-temperature high-pressure reaction kettle, and the other end is connected to the hydrogen sulfide absorbing device. Wherein, more preferably, the hydrogen sulfide absorption device is filled with sodium hydroxide solution.
According to a specific embodiment of the present invention, preferably, the apparatus for testing the adaptability of the water-based completion fluid in the hydrogen sulfide-containing crude oil further comprises a completion fluid storage device, and one end of the completion fluid inlet line is connected to the high-temperature high-pressure reaction kettle, and the other end is connected to the completion fluid storage device.
The invention provides a method and equipment for testing the adaptability of water-based completion fluid in hydrogen sulfide-containing crude oil, which can simulate the interface reaction of the completion fluid and stratum hydrogen sulfide-containing crude oil when the completion fluid is in a well control state, simultaneously adopts the loss degree of hydrogen sulfide in the crude oil to represent experimental pressure, and utilizes the gravity separation principle to simulate the reaction of the completion fluid and the crude oil on a contact interface through the design of a hydrogen sulfide gas inlet mode, so that the actual reaction state of the stratum can be more closely simulated, and the test result can provide a basis for whether the completion fluid can be used in the environment of the hydrogen sulfide-containing crude oil or not, thereby providing experimental basis for the optimization of the completion fluid of a high-pressure sulfur-containing oil and gas well.
Drawings
FIG. 1 is a schematic diagram of the configuration of the apparatus for testing the suitability of the water-based completion fluid provided in example 1 in hydrogen sulfide-containing crude oil;
FIG. 2 is a schematic diagram of the configuration of the apparatus for testing the suitability of the water-based completion fluid provided in example 2 in hydrogen sulfide-containing crude oil;
description of main reference numerals: the high-temperature high-pressure reaction kettle 1, a hydrogen sulfide tank 2, a completion fluid inlet pipeline 3, a completion fluid storage device 4, a gas discharge pipeline 5, a pressure measuring device 6, a hydrogen sulfide absorbing device 7, a heating unit 8, a temperature measuring unit 9, an adjusting unit 10, a pressure reducing regulator 11, a needle valve 12, a check valve 13, a carbon dioxide tank 14, a first tee joint 15 and a second tee joint 16.
Detailed Description
The technical solution of the present invention will be described in detail below for a clearer understanding of technical features, objects and advantageous effects of the present invention, but should not be construed as limiting the scope of the present invention.
Example 1
This embodiment provides an apparatus for testing the suitability of a water-based completion fluid in hydrogen sulfide containing crude oil, as shown in FIG. 1, comprising: a high-temperature high-pressure reaction kettle 1, a hydrogen sulfide tank 2, a completion fluid inlet pipeline 3, a completion fluid storage device 4, a gas discharge pipeline 5, a pressure measuring device 6, a temperature control device and a hydrogen sulfide absorbing device 7; the temperature control device comprises a heating unit 8, a temperature measuring unit 9 and an adjusting unit 10;
wherein the hydrogen sulfide tank 2 is connected with the high-temperature high-pressure reaction kettle 1 through a pipeline; one end of the completion fluid inlet pipeline 3 is connected with the high-temperature high-pressure reaction kettle 1, and the other end is connected with the completion fluid storage device 4; one end of the gas discharge pipeline 5 is connected with the high-temperature high-pressure reaction kettle 1, the other end is connected with the hydrogen sulfide absorbing device 7, and the hydrogen sulfide absorbing device 7 is filled with sodium hydroxide solution; the pressure measuring device 6 is arranged on the gas discharge pipeline 5 through a first tee joint 15; the heating unit 8 is arranged in the high-temperature high-pressure reaction kettle 1; the temperature measuring unit 9 is connected to the high-temperature high-pressure reaction kettle; after the temperature measured by the temperature measuring unit 9 is collected by the adjusting unit 10, the heating intensity of the heating unit 8 is controlled to realize the adjustment of the temperature of the high-temperature high-pressure reaction kettle 1;
A tank opening of the hydrogen sulfide tank 2 is provided with a pressure reducing regulator 11;
the tank opening of the hydrogen sulfide tank 2 is also provided with a pressure supplementing valve, and the pressure supplementing valve comprises a needle valve 12 and a one-way valve 13; the nominal diameter of the needle valve is 5mm.
In this example, the type of autoclave is FCZ3-31/325C276, and the remainder of the apparatus and units are conventional in the art.
Example 2
This embodiment provides an apparatus for testing the suitability of a water-based completion fluid in hydrogen sulfide containing crude oil, as shown in FIG. 2, comprising: a high-temperature high-pressure reaction kettle 1, a hydrogen sulfide tank 2, a carbon dioxide tank 14, a completion fluid inlet pipeline 3, a completion fluid storage device 4, a gas discharge pipeline 5, a pressure measuring device 6, a temperature control device and a hydrogen sulfide absorbing device 7; the temperature control device comprises a heating unit 8, a temperature measuring unit 9 and an adjusting unit 10;
wherein the hydrogen sulfide tank 2 is connected with the high-temperature high-pressure reaction kettle 1 through a pipeline; the carbon dioxide tank 14 is connected to a pipeline connected with the hydrogen sulfide tank 2 and the high-temperature high-pressure reaction kettle 1 through a second tee joint 16; one end of the completion fluid inlet pipeline 3 is connected with the high-temperature high-pressure reaction kettle 1, and the other end is connected with the completion fluid storage device 4; one end of the gas discharge pipeline 5 is connected with the high-temperature high-pressure reaction kettle 1, the other end is connected with the hydrogen sulfide absorbing device 7, and the hydrogen sulfide absorbing device 7 is filled with sodium hydroxide solution; the pressure measuring device 6 is arranged on the gas discharge pipeline 5 through a first tee joint 15; the heating unit 8 is arranged in the high-temperature high-pressure reaction kettle 1; the temperature measuring unit 9 is connected to the high-temperature high-pressure reaction kettle; after the temperature measured by the temperature measuring unit 9 is collected by the adjusting unit 10, the heating intensity of the heating unit 8 is controlled to realize the adjustment of the temperature of the high-temperature high-pressure reaction kettle 1;
The tank opening of the hydrogen sulfide tank 2 is provided with a pressure reducing regulator 11, and the tank opening of the hydrogen sulfide tank 2 is also provided with a one-way valve 13;
a tank opening of the carbon dioxide tank 14 is provided with a pressure reducing regulator 11, and a tank opening of the carbon dioxide tank 14 is also provided with a one-way valve 13;
a needle valve 12 is arranged on a pipeline connected with the high-temperature high-pressure reaction kettle 1 by the second tee joint 16, and the nominal diameter of the needle valve 12 is 5mm.
In this example, the type of autoclave is FCZ3-31/325C276, and the remainder of the apparatus and units are conventional in the art.
Example 3
This example provides a method for testing the suitability of a water-based completion fluid for hydrogen sulfide-containing crude oil using the test apparatus provided in example 1, for CaBr 2 /ZnCl 2 The completion fluid was tested for its suitability in hydrogen sulfide containing crude oil.
The method comprises the following steps:
(1) The completion fluid to be tested (i.e., caBr) was tested at 24 ℃, -28 ℃ and 100 ℃ respectively 2 /ZnCl 2 Completion fluid) and major ion content, the basic properties including density, turbidity, pH value, viscosity, crystallization temperature and the like, and the adopted density tester (model SY-1/3), pH tester (model STARTER 300), turbidity tester (model 1900C) and other equipment instruments are all conventional in the art, and the results are shown in tables 1-4;
TABLE 1CaBr 2 /ZnCl 2 Basic performance detection results of completion fluid at different temperatures
Primary screening:
(a) Pumping 1000mL of crude oil into a high-temperature high-pressure reaction kettle, and then introducing hydrogen sulfide gas into the high-temperature high-pressure reaction kettle for 2 hours until crude oil is saturated with hydrogen sulfide;
(a) 2, deoxidizing the completion fluid to be tested by adopting active carbon, and then introducing 1000mL of the completion fluid to be tested for removing the peroxide into the high-temperature high-pressure reaction kettle;
(a) 3, heating the high-temperature high-pressure reaction kettle to a set temperature, wherein the set temperature is 100 ℃, and adjusting the pressure to normal pressure to be set pressure, and then keeping the pressure stable; measuring the temperature of the high-temperature high-pressure reaction kettle every 3 days, and if the temperature is different from the set temperature, adjusting the temperature of the high-temperature high-pressure reaction kettle to be the same as the set temperature; wherein the temperature of the high-temperature high-pressure reaction kettle is adjusted by the intensity of heating;
(a) After the set reaction time is reached, stopping heating, cooling the high-temperature high-pressure reaction kettle to room temperature, and discharging the fluid in the reaction kettle; wherein the set reaction time is 1 day, 3 days, 7 days, 15 days and 30 days respectively;
(a) -5 detecting the basic properties and the main ion content of the completion fluid after reaction at normal temperature and pressure at 1 day, 3 days, 7 days, 15 days and 30 days respectively, wherein the basic property detection of the completion fluid after reaction at least comprises density detection and pH value detection, and the results are shown in tables 3 and 4;
(a) -6 preliminary judging whether the completion fluid is suitable for hydrogen sulfide containing crude oil: as can be seen from the data in tables 3 and 4, the pH value of the completion fluid to be tested is less than 2, the density change of the completion fluid before and after the reaction is less than 0.2SG, the precipitation amount of the completion fluid after the reaction is more than 100g/1000mL after passing through a 400-mesh filter screen, obvious precipitation exists, the results of repeated experiments are consistent (i.e., the experimental results of 1 day, 3 days, 7 days, 15 days and 30 days are consistent), and the change of the zinc ion content of the completion fluid before and after the reaction is more than 0.05kg/L in a part of repeated experiments, so that the completion fluid is primarily judged to be unsuitable for hydrogen sulfide-containing crude oil;
however, the completion fluid is still subjected to the following steps (2) to (8) to finally determine whether the completion fluid is suitable for hydrogen sulfide-containing crude oil;
(2) Calculating the loss of hydrogen sulfide according to the following formula (1), taking the calculated loss of hydrogen sulfide as the set pressure of the experiment,
in the formula (1),the loss of hydrogen sulfide is expressed in MPa; />The unit is MPa, which is the partial pressure of hydrogen sulfide;is the fugacity coefficient;
wherein the partial pressure of hydrogen sulfide is the partial pressure of hydrogen sulfide in the hydrogen sulfide-containing crude oil, and the specific calculation method is conventional in the art, and is generally obtained by multiplying the total system pressure (namely the formation pressure of the hydrogen sulfide-containing crude oil) by the mole fraction of hydrogen sulfide in the gas phase; coefficient of fugacity SRK squares disclosed on pages 6-8 according to improvement of SRK equation and its application in phase equilibrium calculation (Roming's university of Tianjin's Shuo's treatise on the university of Shuo's 12 2005)The process is calculated by combining a loss coefficient calculation formula of the components in the mixture obtained by a 1-parameter van der Waals mixing rule, namely, the formula (2-34); calculating to obtain the loss of hydrogen sulfide of 5.8MPa;
(3) Pumping 1000mL of crude oil into a high-temperature high-pressure reaction kettle, and then introducing hydrogen sulfide gas into the high-temperature high-pressure reaction kettle for 2 hours until crude oil is saturated with hydrogen sulfide;
(4) Deoxidizing the completion fluid to be tested by adopting active carbon, and then introducing 1000mL of the completion fluid to be tested for removing the peroxide into the high-temperature high-pressure reaction kettle;
(5) Heating a high-temperature high-pressure reaction kettle to a set temperature, wherein the set temperature is 100 ℃, adjusting the pressure to the set pressure obtained in the step (2), namely 5.8MPa, and then keeping the pressure stable; measuring the temperature and the pressure of the high-temperature high-pressure reaction kettle every 3 days, and if the temperature and/or the pressure are different from the set temperature and/or the set pressure, adjusting the temperature and/or the pressure of the high-temperature high-pressure reaction kettle to be the same as the set temperature and the set pressure;
the temperature of the high-temperature high-pressure reaction kettle is adjusted through the heating intensity, the pressure of the high-temperature high-pressure reaction kettle is adjusted through introducing hydrogen sulfide gas, when the measured pressure of the high-temperature high-pressure reaction kettle is lower than the set pressure by more than 0.5MPa, the hydrogen sulfide gas is introduced into the high-temperature high-pressure reaction kettle to supplement the pressure to the set pressure, and when the pressure is adjusted, the flow rate of the hydrogen sulfide gas is less than 10mm/min, and the flow rate is 200mL/min;
(6) After the set reaction time is reached, the pressure is removed, the heating is stopped, the high-temperature high-pressure reaction kettle is cooled to the room temperature, and the fluid in the reaction kettle is discharged; wherein the set reaction time is 7 days;
(7) Detecting the basic performance and the main ion content of the reacted completion fluid at normal temperature and normal pressure, wherein the basic performance detection of the reacted completion fluid at least comprises density detection and pH value detection, and the results are shown in tables 2, 3 and 4;
TABLE 2 detection results of basic Properties and Main ion content of completion fluids before and after reaction at Normal temperature and pressure
TABLE 3 CaBr before and after reaction 2 /ZnCl 2 Detection result of basic performance of completion fluid at normal temperature and normal pressure
TABLE 4 CaBr before and after reaction 2 /ZnCl 2 Detection result of main ion content of completion fluid at normal temperature and normal pressure
(8) The results were: the pH value of the completion fluid to be tested is less than 2, the density change of the completion fluid before and after reaction is less than 0.2SG, but the precipitation amount of the completion fluid after reaction after passing through a 400-mesh filter screen is more than 100g/1000mL, and obvious precipitation exists, so that the completion fluid is not suitable for hydrogen sulfide-containing crude oil.
Claims (15)
1. A method for testing the suitability of a water-based completion fluid in hydrogen sulfide-containing crude oil, comprising the steps of:
(1) Detecting a completion fluid to be detected, wherein the detection at least comprises detection of basic performance of the completion fluid to be detected, and the detection of basic performance of the completion fluid to be detected at least comprises density detection;
(2) Pumping the crude oil into a high-temperature high-pressure reaction kettle, and then introducing hydrogen sulfide gas into the high-temperature high-pressure reaction kettle for a period of time until the crude oil is saturated with hydrogen sulfide;
(3) Deoxidizing the completion fluid to be tested, and then introducing the completion fluid to be tested with the peroxy removed into a high-temperature high-pressure reaction kettle;
(4) Heating the high-temperature high-pressure reaction kettle to a set temperature, and adjusting the pressure to a set pressure, wherein the set pressure is the loss degree of the hydrogen sulfide, and then keeping the hydrogen sulfide stable; measuring the temperature and the pressure of the high-temperature high-pressure reaction kettle once at intervals, and if the temperature and/or the pressure are different from the set temperature and/or the set pressure, adjusting the temperature and/or the pressure of the high-temperature high-pressure reaction kettle to be the same as the set temperature and the set pressure;
(5) After the set reaction time is reached, the pressure is removed, the heating is stopped, the high-temperature high-pressure reaction kettle is cooled to the room temperature, and the fluid in the reaction kettle is discharged;
(6) Detecting a reacted completion fluid, the detecting comprising at least detecting a basic property of the reacted completion fluid, the detecting comprising at least density detecting;
(7) And (3) judging whether the completion fluid is suitable for the hydrogen sulfide-containing crude oil or not at least based on the detection result of the completion fluid to be detected obtained in the step (1) and the detection result of the completion fluid after reaction obtained in the step (6).
2. The method for testing the suitability of a water-based completion fluid for use in hydrogen sulfide-containing crude oil according to claim 1, wherein the testing method further comprises a preliminary screening after step (1), the preliminary screening comprising:
(a) Pumping the crude oil into a high-temperature high-pressure reaction kettle, and then introducing hydrogen sulfide gas into the high-temperature high-pressure reaction kettle for a period of time until crude oil is saturated with hydrogen sulfide;
(a) -2, deoxidizing the completion fluid to be tested, and then introducing the completion fluid to be tested with the peroxide removed into a high-temperature high-pressure reaction kettle;
(a) 3, heating the high-temperature high-pressure reaction kettle to a set temperature, adjusting the pressure to normal pressure to be used as a set pressure, and then keeping the pressure stable; measuring the temperature of the high-temperature high-pressure reaction kettle once at intervals, and if the temperature is different from the set temperature, adjusting the temperature of the high-temperature high-pressure reaction kettle to be the same as the set temperature;
(a) After the set reaction time is reached, stopping heating, cooling the high-temperature high-pressure reaction kettle to room temperature, and discharging the fluid in the reaction kettle;
(a) -5 detecting a reacted completion fluid, the detecting comprising at least a detection of a basic property of the reacted completion fluid, the detection of a basic property of the reacted completion fluid comprising at least a density detection;
(a) -6, based at least on the detection result of the completion fluid to be tested and the detection result of the completion fluid after reaction, preliminarily judging whether the completion fluid is suitable for hydrogen sulfide-containing crude oil, and performing steps (2) to (7) on the completion fluid with the preliminary judgment result being suitable for hydrogen sulfide-containing crude oil to finally judge whether the completion fluid is suitable for hydrogen sulfide-containing crude oil;
preferably, steps (a) -6 further comprise: and (3) carrying out steps (2) - (7) on the completion fluid which is inapplicable to the hydrogen sulfide-containing crude oil as a preliminary judgment result so as to finally judge whether the completion fluid is applicable to the hydrogen sulfide-containing crude oil.
3. The method for testing the suitability of a water-based completion fluid for use in hydrogen sulfide-containing crude oil according to claim 1, wherein in step (1), the basic performance test of the completion fluid to be tested further comprises one or a combination of several of pH test, viscosity test, crystallization temperature test, and turbidity test;
preferably, in step (1), the detection of the completion fluid to be tested further comprises detecting the ion content of the completion fluid to be tested.
4. The method for testing the suitability of the water-based completion fluid according to claim 1 or 2 in hydrogen sulfide-containing crude oil, wherein the amount of crude oil pumped into the high-temperature high-pressure reaction vessel in step (2) and step (a) -1 is 1000 to 3000mL;
Preferably, in the step (2) and the step (a) -1, hydrogen sulfide gas is introduced for 1.5 to 2.5 hours;
preferably, step (2) and step (a) -1 further comprise: introducing carbon dioxide gas into the high-temperature high-pressure reaction kettle for a period of time until crude oil is saturated with hydrogen sulfide and carbon dioxide.
5. The method for testing the adaptability of the water-based completion fluid to the crude oil containing hydrogen sulfide according to claim 1 or 2, wherein the amount of the to-be-tested completion fluid for removing the peroxy gas introduced into the high-temperature high-pressure reaction kettle in the step (3) and the step (a) -2 is 1000-3000 mL.
6. The method for testing the suitability of a water-based completion fluid in hydrogen sulfide-containing crude oil according to claim 1 or 2, wherein in the step (4) and the step (a) -3, the set temperature is the crude oil temperature of the working formation of the completion fluid to be tested, preferably 80-120 ℃;
preferably, in the step (4), the temperature and pressure of the high temperature and high pressure reaction vessel are measured every 60 to 80 hours;
preferably, in step (a) -3, the temperature of the high temperature and high pressure autoclave is measured every 24 to 80 hours.
7. The method for testing the adaptability of the water-based completion fluid to the crude oil containing hydrogen sulfide according to claim 1 or 2, wherein in the step (4), the temperature of the high-temperature high-pressure reaction kettle is adjusted by the intensity of heating, and the pressure of the high-temperature high-pressure reaction kettle is adjusted by introducing hydrogen sulfide gas; preferably, when the measured pressure of the high-temperature high-pressure reaction kettle is lower than the set pressure by more than 0.5MPa, supplementing the pressure to the set pressure by introducing hydrogen sulfide gas into the high-temperature high-pressure reaction kettle; more preferably, the flow rate of the hydrogen sulfide gas is 10mm/min or less and the flow rate is 150 to 250mL/min at the time of pressure adjustment;
Preferably, in step (a) -3, the temperature of the high temperature and high pressure reaction vessel is adjusted by the intensity of heating.
8. The method for testing the suitability of the water-based completion fluid according to claim 1 or 2 in hydrogen sulfide-containing crude oil, wherein in step (5), the set reaction time is 6 to 8 days;
preferably, in step (a) -4, the set reaction time is 1 day to 2 months.
9. The method for testing the suitability of a water-based completion fluid according to claim 1 or 2 in hydrogen sulfide-containing crude oil, wherein in step (6) and steps (a) -5, the basic performance test of the completion fluid after the reaction further comprises one or a combination of several of pH test, viscosity test, crystallization temperature test and turbidity test;
preferably, in step (6) and steps (a) -5, the detecting of the reacted completion fluid further comprises detecting the ion content of the reacted completion fluid.
10. The method of testing the suitability of a water-based completion fluid according to claim 1, 2, 3 or 9 in hydrogen sulfide containing crude oil, wherein in step (7) determining whether the completion fluid is suitable for use in hydrogen sulfide containing crude oil comprises the following: if the density change of the completion fluid before and after the reaction is greater than 0.2SG or if there is significant precipitation of the completion fluid after the reaction, the completion fluid is not suitable for hydrogen sulfide containing crude oil; more preferably, the obvious precipitation is that the precipitation amount after passing through a 300-400-mesh filter screen is more than 100g/1000 mL;
Preferably, in step (7), determining whether the completion fluid is suitable for use with hydrogen sulfide containing crude oil further comprises the following: if the pH value of the completion fluid to be tested is above 2, or if the viscosity of the completion fluid before and after the reaction changes to above 10mPa.s, or if the crystallization temperature of the completion fluid before and after the reaction changes to above 5 ℃, or if the turbidity of the completion fluid before and after the reaction changes to above 10NTU, the completion fluid is not suitable for hydrogen sulfide-containing crude oil;
preferably, in step (7), determining whether the completion fluid is suitable for use with hydrogen sulfide containing crude oil further comprises the following: if the primary ion content of the completion fluid before and after the reaction varies by 0.05kg/L or more, the completion fluid is not suitable for hydrogen sulfide-containing crude oil;
preferably, in steps (a) -6, the preliminary determination of whether the completion fluid is suitable for use with hydrogen sulfide containing crude oil includes the following: if the density change of the completion fluid before and after the reaction is greater than 0.2SG or if there is significant precipitation of the completion fluid after the reaction, the completion fluid is not suitable for hydrogen sulfide containing crude oil; if the density change of the completion fluid before and after the reaction is below 0.2SG and no obvious precipitation exists in the completion fluid after the reaction, preliminarily judging that the completion fluid is suitable for the hydrogen sulfide-containing crude oil; more preferably, the obvious precipitation is that the precipitation amount after passing through a 300-400-mesh filter screen is more than 100g/1000 mL;
Preferably, in steps (a) -6, the preliminary determination of whether the completion fluid is suitable for use with hydrogen sulfide containing crude oil further comprises the following means: if the pH value of the completion fluid to be tested is above 2, or if the viscosity of the completion fluid before and after the reaction changes to above 10mPa.s, or if the crystallization temperature of the completion fluid before and after the reaction changes to above 5 ℃, or if the turbidity of the completion fluid before and after the reaction changes to above 10, the completion fluid is not suitable for hydrogen sulfide-containing crude oil;
preferably, in steps (a) -6, the preliminary determination of whether the completion fluid is suitable for use with hydrogen sulfide containing crude oil further comprises the following means: if the primary ion content of the completion fluid before and after the reaction varies by 0.05kg/L or more, the completion fluid is not suitable for hydrogen sulfide-containing crude oil.
11. A test apparatus for testing the suitability of a water-based completion fluid in a hydrogen sulfide containing crude oil for implementing a test method of the suitability of a water-based completion fluid according to any one of claims 1-10 in a hydrogen sulfide containing crude oil, said apparatus comprising at least: the high-temperature high-pressure reaction kettle, the hydrogen sulfide tank, the completion fluid inlet pipeline, the gas discharge pipeline, the pressure measuring device and the temperature control device; the temperature control device comprises a heating unit, a temperature measuring unit and an adjusting unit;
Wherein the hydrogen sulfide tank is connected with the high-temperature high-pressure reaction kettle through a pipeline; the completion fluid inlet pipeline is connected to the high-temperature high-pressure reaction kettle; the gas exhaust pipeline is connected to the high-temperature high-pressure reaction kettle; the pressure measuring device is arranged on the gas discharge pipeline through a tee joint; the heating unit is arranged in the high-temperature high-pressure reaction kettle; the temperature measuring unit is connected to the high-temperature high-pressure reaction kettle; and after the temperature measured by the temperature measuring unit is collected by the adjusting unit, the heating intensity of the heating unit is controlled to realize the adjustment of the temperature of the high-temperature high-pressure reaction kettle.
12. The apparatus for testing the suitability of a water-based completion fluid for use in hydrogen sulfide containing crude oil of claim 11, wherein a tank port of the hydrogen sulfide tank is provided with a pressure reducing regulator.
13. The test apparatus for the suitability of a water-based completion fluid in hydrogen sulfide-containing crude oil according to claim 11, wherein a tank port of the hydrogen sulfide tank is provided with a pressure-supplementing valve which controls a needle valve and a check valve; preferably, the nominal diameter of the needle valve is 5mm.
14. The apparatus for testing the suitability of a water-based completion fluid for use in hydrogen sulfide-containing crude oil according to claim 11, wherein said apparatus further comprises a carbon dioxide tank connected to a pipeline of said hydrogen sulfide tank connected to said high temperature and high pressure reactor through a tee.
15. The test apparatus for the suitability of a water-based completion fluid for use in hydrogen sulfide-containing crude oil according to claim 11, wherein said test apparatus further comprises a hydrogen sulfide absorbing means, one end of said gas discharge line being connected to said high temperature and high pressure reactor vessel, the other end being connected to said hydrogen sulfide absorbing means; preferably, the hydrogen sulfide absorption device is filled with sodium hydroxide solution.
Priority Applications (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202211207530.4A CN117846542A (en) | 2022-09-30 | 2022-09-30 | Method and equipment for testing adaptability of water-based completion fluid in hydrogen sulfide-containing crude oil |
| PCT/CN2023/104395 WO2024066592A1 (en) | 2022-09-30 | 2023-06-30 | Test method and device for the adaptability of water-based completion fluid in crude oil containing hydrogen sulfide |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202211207530.4A CN117846542A (en) | 2022-09-30 | 2022-09-30 | Method and equipment for testing adaptability of water-based completion fluid in hydrogen sulfide-containing crude oil |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN117846542A true CN117846542A (en) | 2024-04-09 |
Family
ID=90475954
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202211207530.4A Pending CN117846542A (en) | 2022-09-30 | 2022-09-30 | Method and equipment for testing adaptability of water-based completion fluid in hydrogen sulfide-containing crude oil |
Country Status (2)
| Country | Link |
|---|---|
| CN (1) | CN117846542A (en) |
| WO (1) | WO2024066592A1 (en) |
Family Cites Families (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US8048827B2 (en) * | 2006-08-03 | 2011-11-01 | Baker Hughes Incorporated | Kinetic gas hydrate inhibitors in completion fluids |
| US7519481B2 (en) * | 2006-09-11 | 2009-04-14 | Tetra Tech | System and method for predicting compatibility of fluids with metals |
| CN104213905B (en) * | 2013-06-05 | 2018-04-03 | 中国石油天然气股份有限公司 | Automatic well killing process method and device for downhole operation |
| CN103645285A (en) * | 2013-12-17 | 2014-03-19 | 中国海洋石油总公司 | Visualized natural gas hydrate simulation test device and method |
| CN104155232B (en) * | 2014-07-31 | 2017-01-18 | 中国石油大学(北京) | Device for evaluating sulfur resistance of gel used in well completion process of unbalanced drill |
| CN107159058A (en) * | 2017-06-29 | 2017-09-15 | 新疆科力新技术发展股份有限公司 | The method for automating high-temperature high-voltage reaction device and gasification and non-vaporized synthesis |
| CN207396273U (en) * | 2017-10-18 | 2018-05-22 | 西南石油大学 | A kind of experimental provision for measuring sulphur deposition influence factor in polymorphic type pit shaft |
| CN111089940A (en) * | 2018-10-24 | 2020-05-01 | 中国石油化工股份有限公司 | Evaluation device and evaluation method for desulfurization effect of desulfurizing agent |
| CN114214052A (en) * | 2021-12-13 | 2022-03-22 | 中海石油(中国)有限公司 | Compound corrosion inhibitor for high-density completion fluid in micro-sulfur-containing environment and preparation method and application thereof |
-
2022
- 2022-09-30 CN CN202211207530.4A patent/CN117846542A/en active Pending
-
2023
- 2023-06-30 WO PCT/CN2023/104395 patent/WO2024066592A1/en not_active Ceased
Also Published As
| Publication number | Publication date |
|---|---|
| WO2024066592A1 (en) | 2024-04-04 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN102169112B (en) | Device and method for research of low-dosage inhibitor of natural gas hydrate | |
| NO20064289L (en) | Method and apparatus for estimating physical parameters in underground reservoirs | |
| CN111551482B (en) | Comprehensive dynamic water corrosion test device with high-temperature and high-pressure one-loop and two-loop linkage operation | |
| CN108474776B (en) | Method and system for measuring sulfur solubility in gases | |
| CN104483227A (en) | Sulfur deposition device based on magnetic suspension balance | |
| CN106124354A (en) | The sulfur solubility online testing device of acid gas reservoir and method | |
| CN110865010B (en) | A multi-gas seepage test device and test method under rock rheological loading conditions | |
| CN106990010A (en) | Liquid erosion test device in a kind of many reference amounts regulation and control pipeline | |
| CN117846542A (en) | Method and equipment for testing adaptability of water-based completion fluid in hydrogen sulfide-containing crude oil | |
| CN207396480U (en) | Sour gas water content and the integrated test device of PVT high-pressure fluid physical property | |
| CN104502552A (en) | High-temperature and high-pressure foam static filter tester and application thereof | |
| DK181152B1 (en) | A method for subjecting at least one sample to a dynamic liquid CO2 or a supercritical CO2 environment and a test system thereof | |
| CN212844929U (en) | Test device for simulating corrosion of supercritical carbon dioxide conveying pipeline | |
| CN105675803A (en) | Gas calibration device and method applied to under-balanced drilling UBD | |
| Zhang et al. | Corrosion risk assessment of geothermal reinjection wellbore in Xining Basin, China | |
| Lasebikan et al. | The effect of hydrogen sulphide on ammonium bisulphite when used as an oxygen scavenger in aqueous solutions | |
| US12360098B2 (en) | Analytical determination of dissolved gas concentration in water pipelines | |
| CN207798802U (en) | A kind of temperature control test the speed of paraffin dissolution device with pressure | |
| CN111337622A (en) | Method for quantitatively evaluating static stability of water-based completion fluid in different density sections | |
| Kunju et al. | Experimental Investigation of Absorption and Desorption of Gas in Riser During MPD Well Control | |
| Bachu et al. | Factors affecting the chromatographic partitioning of CO2 and H2S injected into a water-saturated porous medium | |
| Kovacs et al. | Thermodynamic Modeling of Gas Charging Techniques | |
| CN108844998B (en) | Gravity self-flowing anhydrous hydrogen fluoride liquid sampling and online analysis device | |
| CN202531134U (en) | Top air injection gravity assisted flooding oil extraction one-dimensional physical simulation experiment system | |
| CN214844607U (en) | Experimental device for measuring solubility of carbon dioxide-formation water interaction |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination |