CN104594861A - Hydrate inhibitor filling method for deepwater gas field development - Google Patents
Hydrate inhibitor filling method for deepwater gas field development Download PDFInfo
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- CN104594861A CN104594861A CN201410722764.1A CN201410722764A CN104594861A CN 104594861 A CN104594861 A CN 104594861A CN 201410722764 A CN201410722764 A CN 201410722764A CN 104594861 A CN104594861 A CN 104594861A
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- 239000003112 inhibitor Substances 0.000 title claims abstract description 75
- 238000000034 method Methods 0.000 title claims abstract description 33
- 238000011161 development Methods 0.000 title claims abstract description 30
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 claims abstract description 123
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 118
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims abstract description 42
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 claims abstract description 18
- 239000008398 formation water Substances 0.000 claims abstract description 18
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 claims abstract description 11
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims abstract description 8
- 238000012545 processing Methods 0.000 claims abstract description 7
- 239000007789 gas Substances 0.000 abstract description 85
- 239000003345 natural gas Substances 0.000 abstract description 10
- 238000004519 manufacturing process Methods 0.000 abstract description 6
- 238000010276 construction Methods 0.000 abstract description 2
- 230000007613 environmental effect Effects 0.000 abstract 1
- 235000019441 ethanol Nutrition 0.000 abstract 1
- 238000002474 experimental method Methods 0.000 description 9
- NMJORVOYSJLJGU-UHFFFAOYSA-N methane clathrate Chemical compound C.C.C.C.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O NMJORVOYSJLJGU-UHFFFAOYSA-N 0.000 description 8
- 238000004458 analytical method Methods 0.000 description 6
- 230000015572 biosynthetic process Effects 0.000 description 6
- 239000002131 composite material Substances 0.000 description 6
- 230000000694 effects Effects 0.000 description 6
- 238000003786 synthesis reaction Methods 0.000 description 6
- 230000000903 blocking effect Effects 0.000 description 5
- 239000013078 crystal Substances 0.000 description 5
- 238000005429 filling process Methods 0.000 description 4
- 230000005764 inhibitory process Effects 0.000 description 4
- 150000002500 ions Chemical class 0.000 description 3
- 150000001875 compounds Chemical class 0.000 description 2
- 239000000470 constituent Substances 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
- 238000005457 optimization Methods 0.000 description 2
- 239000004576 sand Substances 0.000 description 2
- 238000013459 approach Methods 0.000 description 1
- 239000008346 aqueous phase Substances 0.000 description 1
- 238000005452 bending Methods 0.000 description 1
- 238000000354 decomposition reaction Methods 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 239000002274 desiccant Substances 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 150000004677 hydrates Chemical class 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 238000011835 investigation Methods 0.000 description 1
- 239000012071 phase Substances 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 230000006641 stabilisation Effects 0.000 description 1
- 239000002699 waste material Substances 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
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/0007—Equipment or details not covered by groups E21B15/00 - E21B40/00 for underwater installations
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- 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)
- Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
Abstract
The invention relates to a hydrate inhibitor filling method for deepwater gas field development and belongs to the technical field of hydrate inhibitor. The hydrate inhibitor filling method for deepwater gas field development comprises the processing steps that 1, the temperature and water depth environmental parameters of a deepwater gas well are determined, wherein the temperature ranges from 3 DEG C to 18.8 DEG C, and the depth of water ranges from 100 m to 1350 m; 2, natural gas components in the deepwater gas well are analyzed and determined, wherein methane accounts for 85%-87%, and ethane accounts for 13%-15%; 3, the formation water salinity of the deepwater gas well is analyzed and determined, wherein the content of K+ and Na+ ranges from 7390 mg/L to 7944 mg/L, the content of Ca2+ ranges from 242 mg/L to 512 mg/L, the content of Mg2+ ranges from 45 mg/L to 50.4 mg/L, the content of Cl- ranges from 11778 mg/L to 12500 mg/L, and the content of SO42- ranges from 115 mg/L to 206 mg/L; 4, the hydrate inhibitor is added into the deepwater gas well, wherein the hydrate inhibitor added into the deepwater gas well is methyl alcohol or ethylene glycol or ethyl alcohol, and the mass ratio of the amount of the added hydrate inhibitor to the water ranges from 0.01 wt/wt to 1.3 wt/wt. The hydrate inhibitor filling method has the advantages that operation is convenient, controllability is good, blockage, caused by generation of a hydrate, of a pipeline or a valve can be effectively avoided, the use amount of the inhibitor is reduced, and safety production and construction during deepwater gas field development are guaranteed.
Description
Technical field
The invention belongs to hydrate inhibitor technical field, particularly relate to a kind of deep water gas field development hydrate inhibitor charging method.
Background technology
Gas hydrates also claim hydrate, and it is a kind of solid crystal thing being wrapped in the water of little gas molecule.In gas course of conveying, cause there is water in pipeline because desiccant performance is not good, or the change of the factors such as aquifer yield increases, gas componant is different, formation water salinity there are differences, causes hydrate inhibitor adding amount not meet the demands, the effect suppressing gas hydrate synthesis can not be played.In the manufacturing process of deep water gas field, because bottom-water temperature is low, pressure is high, more easily form gas hydrate, especially near the mud line of seabed, cause the blocking such as tubing string, submerged pipeline, production tree.If gas enters airtight annular space and forms hydrate, be heated suddenly at production period, decomposition of hydrate, inner sleeve can be caused to cave in for consequent pressure or outer sleeve breaks.In addition, oil-gas hydrate chock high-speed mobile, in the place that pipeline section is bending, hydrate chock can puncture pipeline with strength like shell, causes the infringement of personnel and equipment.Therefore, should avoid as far as possible generating gas hydrate.
At present, research in hydrate inhibitor charging method, seldom relate to deep water gas field development, and carry out adding amount when determining, do not consider the impact of the composite factors such as gas component, formation water salinity, the depth of water, just simple some influence factor of concern, and have ignored the combined influence of these factors.Hu Yiwu etc. (2006) set forth with regard to the impact of ethylene glycol filling parameter on hydrate inhibition effect in the whole technique of Kela 2 Gas Field treatment plant of central authorities, but do not consider the impact (people such as Hu Yiwu of the composite factor such as gas component, formation water salinity, the investigation of low temperature separating process ethylene glycol injected system, natural gas and oil, 2006,24th volume, the 3rd phase, 19-21 page).Gaurav Gupta etc. (2012) point out, improve the reliability of the uncertain factors such as aquifer yield measurement, the measurement of MEG injection rate, just can progressively reduce MEG excess dose, but do not indicate yet and how to determine inhibitor filling parameter (Gaurav Gupta and Sunil Kumar Singh when considering these factors, Hydrate Inhibition Optimization in Deep Water Field, SPE 153504,2012).This hydrate inhibitor consumption not considering actual condition, can affect hydrate inhibition effect, even cause certain damage sequence, and excessive inhibitor consumption also can cause the problems such as the waste of inhibitor.
Summary of the invention
The present invention provides a kind of deep water gas field development hydrate inhibitor charging method for solving in known technology the technical problem that exists.
The object of this invention is to provide one, to have technique simple, easy to operate, controllability is good, the blockage problem such as pipeline, valve effectively avoiding hydrate to generate causing, save inhibitor consumption, ensure the deep water gas field development hydrate inhibitor charging method of the features such as deep water gas field development safety in production construction.
The present invention optimizes hydrate inhibitor adding amount, saves inhibitor consumption, under deep-water subsea low temperature, condition of high voltage, improves hydrate inhibition effect, for deep water gas field development provides flowing safety guarantee.
Of the present inventionly be applicable to deep water gas field development hydrate inhibitor charging method, comprise the steps:
The respective environment parameter of step 1, mensuration deep water gas well, specifically comprises the depth of water of deep water gas well and the temperature at different water depth place; Step 2, the natural gas sample gathered in deep water gas well, carry out constituent analysis to natural gas sample, determine the degree of each component in natural gas; Step 3, the water sample gathered in deep water gas well, carry out formation water salinity analysis to water sample, determine corresponding formation water ions content; Step 4, the natural gas sample gathered is carried out to indoor water symphysis and becomes prognostic experiment, record suppresses the critical of the hydrate inhibitor needed for gas hydrate synthesis.
The technical scheme that deep water gas field development hydrate inhibitor charging method of the present invention is taked is:
A kind of deep water gas field development hydrate inhibitor charging method, is characterized in that: hydrate inhibitor filling comprises following processing step
(1) temperature and the depth of water ambient parameter of deep water gas well is determined: temperature is 3 DEG C-18.8 DEG C, the depth of water is 100m-1350m;
(2) gas component determined in deep water gas well is analyzed: methane 85%-87%, ethane 13%-15%;
(3) formation water salinity determined in deep water gas well is analyzed: K
+and Na
+content is 7390-7944mg/L, Ca
2+content is 242-512mg/L, Mg
2+content is 45-50.4mg/L, Cl
-content is 11778-12500mg/L, SO4
2-content is 115-206mg/L;
(4) deep water gas well adds hydrate inhibitor: add hydrate inhibitor methyl alcohol, ethylene glycol or ethanol in deep water gas well, and the addition of hydrate inhibitor and the mass ratio of water are 0.01-1.3wt/wt.
Deep water gas field development hydrate inhibitor charging method of the present invention can also adopt following technical scheme:
Described deep water gas field development hydrate inhibitor charging method, is characterized in: when determining temperature and the depth of water ambient parameter of deep water gas well, deep well pressure is 2.5-28.2MPa.
Described deep water gas field development hydrate inhibitor charging method, is characterized in: the purity of hydrate inhibitor ethylene glycol is 90-96%.
The advantage that the present invention has and good effect are:
Deep water gas field development hydrate inhibitor charging method is owing to have employed the brand-new technical scheme of the present invention, compared with prior art, the present invention is directed in deep water gas field development process due to low temperature, high pressure, the depth of water etc. are easy to the special operation condition forming hydrate, one is provided to be applicable to deep water gas field development hydrate inhibitor charging method, this charging method is by considering gas component, formation water salinity, the impact of the composite factors such as the depth of water, optimize hydrate inhibitor filling parameter, hydrate is effectively avoided to generate the pipeline caused, the blockage problem such as valve, save inhibitor consumption, thus overcome the deficiency existed in existing charging method, for deep water gas field development flowing safety provides safeguard.
Accompanying drawing explanation
Fig. 1 is deep water gas field development hydrate inhibitor charging method schematic flow sheet of the present invention;
Detailed description of the invention
For summary of the invention of the present invention, Characteristic can be understood further, hereby exemplify following examples, and be described in detail as follows:
Accompanying drawings 1.
Embodiment 1
A kind of deep water gas field development hydrate inhibitor charging method, its filling process comprises following processing step:
(1) temperature and the depth of water ambient parameter of deep water gas well is determined: temperature 18.8 DEG C, the depth of water are 100m, pressure 28.8MPa;
(2) gas component determined in deep water gas well is analyzed: methane 85%, ethane 15%;
(3) formation water salinity determined in deep water gas well is analyzed: K
+and Na
+content is 7390mg/L, Ca
2+content is 242mg/L, Mg
2+content is 45mg/L, Cl
-content is 11778mg/L, SO4
2-content is 115mg/L;
(4) deep water gas well adds hydrate inhibitor: add hydrate inhibitor ethylene glycol in deep water gas well, and the purity of hydrate inhibitor ethylene glycol is 90%, and the addition of hydrate inhibitor ethylene glycol and the mass ratio of water are 0.01wt/wt.
After adding hydrate inhibitor ethylene glycol in deep water gas well, effectively can reduce hydrate and generate, the risk preventing pipeline from blocking occurs.
Embodiment 2
A kind of deep water gas field development hydrate inhibitor charging method, its filling process comprises following processing step:
(1) temperature and the depth of water ambient parameter of deep water gas well is determined: temperature is 3 DEG C, the depth of water is 1350m;
(2) gas component determined in deep water gas well is analyzed: methane 87%, ethane 15%;
(3) formation water salinity determined in deep water gas well is analyzed: K
+and Na
+content is 7944mg/L, Ca
2+content is 512mg/L, Mg
2+content is 50.4mg/L, Cl
-content is 12500mg/L, SO4
2-content is 206mg/L;
(4) deep water gas well adds hydrate inhibitor: add hydrate inhibitor ethylene glycol in deep water gas well, and the purity of hydrate inhibitor ethylene glycol is 90%, and the addition of hydrate inhibitor ethylene glycol and the mass ratio of water are 1.3wt/wt.
After adding hydrate inhibitor ethylene glycol in this deep water gas well, effectively can reduce hydrate and generate, the risk preventing pipeline from blocking occurs.
Embodiment 3
A kind of deep water gas field development hydrate inhibitor charging method, its filling process comprises following processing step:
(1) temperature and the depth of water ambient parameter of deep water gas well is determined: temperature is 10 DEG C, the depth of water is 1000m, pressure 12MPa;
(2) gas component determined in deep water gas well is analyzed: methane 86.2%, ethane 14.5%;
(3) formation water salinity determined in deep water gas well is analyzed: K
+and Na
+content is 7684mg/L, Ca
2+content is 352mg/L, Mg
2+content is 48.3mg/L, Cl
-content is 11980mg/L, SO4
2-content is 165mg/L;
(4) deep water gas well adds hydrate inhibitor: add hydrate inhibitor methyl alcohol in deep water gas well, and the addition of hydrate inhibitor methyl alcohol and the mass ratio of water are 1.0wt/wt.
After adding hydrate inhibitor methyl alcohol in this deep water gas well, effectively can reduce hydrate and generate, reach the technique effect of the risk generation preventing pipeline from blocking.
Embodiment 4
A kind of deep water gas field development hydrate inhibitor charging method, consider that various composite factor comprises the composite factors such as gas component, formation water salinity, the depth of water, its filling process comprises following processing step:
The respective environment parameter of step 1, mensuration deep water gas well, specifically comprises the depth of water of deep water gas well and the temperature at different water depth place.
In this embodiment, maximum shut-in pressure 28.2MPa, the corresponding gas well depth of water is 1350m, and different water depth place temperature is as shown in table 1.
Table 1 different water depth place Temperature Distribution
Step 2, the natural gas sample gathered in deep water gas well, carry out constituent analysis to natural gas sample, determine the degree of each component in natural gas.
In this embodiment, to the natural gas sample taking from L3 deep water gas well 3065.1m depth sand 1 Reservoir Section, carry out gas component analysis, determine gaseous species and content.Gas component is: methane 85%-87%, ethane 13%-15%.
Step 3, the water sample gathered in deep water gas well, carry out formation water salinity analysis to this water sample, determine corresponding formation water ions content.
In this embodiment, formation water salinity analysis is carried out to the water sample taking from L3 deep water gas well sand 1 Reservoir Section, determines ion concentration, K
+and Na
+content is 7390-7944mg/L, Ca
2+content is 242-512mg/L, Mg
2+content is 45-50.4mg/L, Cl
-content is 11778-12500mg/L, SO
4 2-content is 115-206mg/L.
Step 4, gas component, formation water salinity, the depth of water etc. for different, carrying out indoor water symphysis becomes prognostic experiment, suppresses the critical compound inhibitors threshold dose needed for gas hydrate synthesis under determining different condition.
In this embodiment, the ethylene glycol (accounting for aqueous phase mass percent) of the hydrate inhibitor of employing to be concentration be 90wt%.Change inhibitor consumption, observe gas hydrate synthesis situation, determine the inhibitor threshold dose forming hydrate.
Hydrate inhibitor adding amount described in the present invention is by measuring with the mass ratio (wt/wt) of water, and e.g., 1.2wt/wt represents that ethylene glycol injects 1.2 times that weight is equivalent to water weight.
(1) seabed minimum temperature 3 DEG C, methane content 85%, ethane content 15%, K
+and Na
+content is 7390mg/L, Ca
2+content is 242mg/L, Mg
2+content is 45mg/L, Cl
-content is 11778mg/L, SO
4 2-content is 115mg/L, changes the adding amount of ethylene glycol, observes hydrate and generates situation.
1. ethylene glycol adding amount is 0wt/wt: when not adding ethylene glycol, that is, when ethylene glycol adding amount is 0wt/wt, just define hydrate during pressure 2.5MPa.
2. ethylene glycol adding amount is 2wt/wt: when ethylene glycol adding amount is 2wt/wt, do not form hydrate.At this moment, keep experiment condition constant, by stable experiment 3 days or longer a period of time, see and whether can form hydrate.After a period of stabilisation, do not form hydrate, so, reduce ethylene glycol adding amount, carry out next group experiment.
Stable a period of time described in the present invention includes but not limited to 3 days.
3. ethylene glycol adding amount is 1wt/wt: when ethylene glycol adding amount is 1wt/wt, define crystal of hydrate soon in experimentation, and continuing increases ethylene glycol adding amount, observation experiment situation.
4. ethylene glycol adding amount is 1.5wt/wt: when ethylene glycol adding amount is 1.5wt/wt, do not form crystal of hydrate in experimentation.By stable experiment a period of time, do not have crystal of hydrate to be formed yet, reduce ethylene glycol adding amount, carry out next group experiment.
5. add 1.2wt/wt ethylene glycol, 1.4wt/wt ethylene glycol, 1.3wt/wt ethylene glycol successively, and stablize a period of time respectively, observe crystal of hydrate situation, finally determine that the critical ethylene glycol consumption under this temperature condition is 1.3wt/wt.
Ethylene glycol adding amount described in the present invention chooses the adding amount that mode includes but not limited to the present invention relates to.
(2) depth of water 500m, minimum temperature 10 DEG C, methane 86%, ethane 14%, K
+and Na
+content is 7500mg/L, Ca
2+content is 300mg/L, Mg
2+content is 48mg/L, Cl
-content is 12000mg/L, SO
4 2-content is 160mg/L, changes the adding amount of ethylene glycol, observes hydrate and generates situation.
Adopt the similar approach in (1), change ethylene glycol adding amount, finally obtaining critical ethylene glycol consumption is 1.0wt/wt.
(3) depth of water 100m, minimum temperature 18.8 DEG C, methane 87%, ethane 13%, K
+and Na
+content is 7944mg/L, Ca
2+content is 512mg/L, Mg
2+content is 50.4mg/L, Cl
-content is 12500mg/L, SO
4 2-content is 206mg/L, changes the adding amount of ethylene glycol, observes hydrate and generates situation.
Known by experiment, during depth of water 100m, minimum temperature 18.8 DEG C, the pressure forming hydrate under this condition will up to 45MPa.Therefore, can not hydrate be formed under maximum shut-in pressure 28.2MPa condition, not need filling ethylene glycol inhibitor.
Under maximum shut-in pressure 28.2MPa condition, when temperature be 3 DEG C-18.8 DEG C, the depth of water is 100m-1350m, methane 85%-87%, ethane 13%-15%, K
+and Na
+content is 7390-7944mg/L, Ca
2+content is 242-512mg/L, Mg
2+content is 45-50.4mg/L, Cl
-content is 11778-12500mg/L, SO
4 2-when content is 115-206mg/L, the critical ethylene glycol consumption needed for gas hydrate synthesis is suppressed to be 0.01wt/wt-1.3wt/wt.
Known by analyzing above, under different working condition, suppress the critical compound inhibitors adding amount needed for gas hydrate synthesis, need to consider the composite factors such as gas component, formation water salinity, the depth of water, carry out hydrate inhibitor filling parameter optimization and can reduce the risk that hydrate generates blocking pipeline.
It is simple that the present embodiment has described technique, easy to operate, the advantages such as controllability is good, and the blockage problem such as pipeline, valve effectively avoiding hydrate to generate causing, saves inhibitor consumption, ensure that deep water gas field development is kept the safety in production and construct.
Claims (3)
1. a deep water gas field development hydrate inhibitor charging method, is characterized in that: hydrate inhibitor filling comprises following processing step
(1) temperature and the depth of water ambient parameter of deep water gas well is determined: temperature is 3 DEG C-18.8 DEG C, the depth of water is 100m-1350m;
(2) gas component determined in deep water gas well is analyzed: methane 85%-87%, ethane 13%-15%;
(3) formation water salinity determined in deep water gas well is analyzed: K
+and Na
+content is 7390-7944mg/L, Ca
2+content is 242-512mg/L, Mg
2+content is 45-50.4mg/L, Cl
-content is 11778-12500mg/L, SO4
2-content is 115-206mg/L;
(4) deep water gas well adds hydrate inhibitor: add hydrate inhibitor methyl alcohol, ethylene glycol or ethanol in deep water gas well, and the addition of hydrate inhibitor and the mass ratio of water are 0.01-1.3wt/wt.
2. deep water gas field development hydrate inhibitor charging method according to claim 1, is characterized in that: when determining temperature and the depth of water ambient parameter of deep water gas well, deep well pressure is 2.5-28.2MPa.
3. deep water gas field development hydrate inhibitor charging method according to claim 1 and 2, is characterized in that: the purity of hydrate inhibitor ethylene glycol is 90-96%.
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| CN106194165A (en) * | 2016-08-26 | 2016-12-07 | 中国石油大学(华东) | Gas hydrates blocking monitoring device and method in the test of deep water gas well |
| CN110531049A (en) * | 2019-08-01 | 2019-12-03 | 北京市燃气集团有限责任公司 | A kind of combustion gas yard determines the measurement method and device of hydrate inhibitor injection rate |
| CN113669047A (en) * | 2021-07-08 | 2021-11-19 | 中石化石油工程技术服务有限公司 | High-temperature high-pressure oil and gas well testing device and method |
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