CN1464173A - Modified tannin extract gel water plugging technology suitable for high-temperature high-salt oil reservoir - Google Patents
Modified tannin extract gel water plugging technology suitable for high-temperature high-salt oil reservoir Download PDFInfo
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- 235000018553 tannin Nutrition 0.000 title claims abstract description 40
- 229920001864 tannin Polymers 0.000 title claims abstract description 40
- 239000001648 tannin Substances 0.000 title claims abstract description 40
- 238000005516 engineering process Methods 0.000 title abstract description 5
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 34
- 239000004568 cement Substances 0.000 claims abstract description 18
- 238000002347 injection Methods 0.000 claims abstract description 17
- 239000007924 injection Substances 0.000 claims abstract description 17
- 238000007789 sealing Methods 0.000 claims abstract description 10
- 239000002981 blocking agent Substances 0.000 claims description 28
- 238000000034 method Methods 0.000 claims description 16
- 150000003839 salts Chemical class 0.000 claims description 15
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- 239000003513 alkali Substances 0.000 claims description 3
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Abstract
A modified tannin extract gel water plugging technology suitable for high-temperature and high-salt oil reservoirs adopts three plugs to inject water plugging, wherein the first plug is as follows: the temporary plugging agent accounts for 10-20% of the total injection amount, and the temporary plugging agent is injected and then closes the well and waits for solidification within 0.5-1.5 h; selectively enabling the subsequently injected second slug high-dosage low-viscosity plugging agent main agent sol to enter a water layer, wherein the second slug high-dosage low-viscosity plugging agent main agent sol accounts for 70-80% of the total injection amount; the third section of the plug is cement which is used as a sealing agent and accounts for 10-20% of the total injection amount, so that the plugging agent selectively enters a water layer; the main agent of the plugging agent can resist high temperature and hypersalinity and has long-term thermal stability; the formed plugging layer has the strength required by long-term scouring of high-pressure-resistant formation water, so that the aims of reducing the water content of the oil well in the later oil extraction stage of the high-temperature high-salt oil reservoir, increasing the oil production and reducing the production cost are fulfilled.
Description
Relate to the field.
The invention belongs to the raising petroleum recovery technology of oil field development, specifically, is a kind of modified tannin extract gel water-plugging technique that is applicable to high temperature and high salt oil deposit.
Background technology.
At the existing report of the desk research work of High Temperature Plugging Agent
[1 ~ 3], human Acacia extract and sulfonation tannin extract and the mixed gels that can be applied in the high-temperature stratum shutoff that got such as formaldehyde and phenol such as Canadian Navratil
[1,2]People such as Liu Chengjie utilize the rubber tannin extract of sighing to make the blocking agent that can be used for high temperature
[3]But successful water plugging and profile controlling field trial is not appeared in the newspapers.Existing techniques of chemical water plugging is used for＞and the heat stability of chemical agent will appear during 90 ℃ oil reservoir, and when general the injection, do not possess selective shut-off ability and gel strength and can not reach long-term high pressure and wash away required intensity and problems such as shutoff does not live occur.Its reason has: the oil well aquifer pressure is higher than formation pressure, and blocking agent easily enters oil reservoir when directly injecting, and causes not water blockoff of stifled oil; The polymer class blocking agent can not form stabilizing gel after temperature is higher than 120 ℃; The easily anti-row of particulate species blocking agent; Cement class blocking agent is difficult to heavy dose of the injection, after solidifying in oil-sand, because of still there is the slit in existing of oil-sand sea surface oil slick between cement and oil-sand, can not form stable shutoff.
Related background document is: [1] Navratil M et al.Method for reducing the permeability of underground strata during secondary recovery oil[P].
CA?Patent?1187404.1985，5，21.[2] Navratil?M?et?al.Compositions?and?methods?for?reducing?the?permeability?of?underground?strata[P].US?Patent
4663367.1987,5,5.[3] Liu Chengjie. the research [J] of compound thermal recovery blocking agent PST. oilfield chemistry, 1995,128 (2): 237～241.[4] Zhu Huaijiang, Luo Yousong, Weng Rui, Deng. larch modified tannin extract solution and gelling properties research [J]. oilfield chemistry, 1998,15 (3): 248～252.[5] Wang Xiaoquan, the horse bezoar fork. adjust the High Temperature Plugging Agent [J] that the steam injection profile is used. oilfield chemistry, 1991,8 (1): 74～78.[6] Sun Dawang. vegatable tannin chemistry [M]. Beijing: China Forest publishing house, 1992:423～425.
Summary of the invention
The object of the present invention is to provide a kind of blocking agent selectivity that makes to enter water layer; Blocking agent the host high temperature resistant and anti-high salinity of energy also has long-term thermal stability; The plugged zone that forms has high pressure resistant formation water and washes away required intensity for a long time, thereby reach the moisture content that reduces high temperature and high salt oil deposit oil recovery later stage oil well, increase oil production, the modified tannin extract gel water-plugging technique that is applicable to high temperature and high salt oil deposit of the purpose that reduces production costs.
The present invention is achieved in that and adopts three slugs to inject water blockoff that first slug is: diverting agent such as, it accounts for and injects 10～20% of total amount, diverting agent inject the back 0.5～1.5h in the time closing well wait and coagulate; The heavy dose of low viscosity blocking agent of second slug host colloidal sol selectivity of follow-up injection is entered water layer, and it accounts for and injects 70～80% of total amount; Thereafter the 3rd slug is a cement, as sealing compound, accounts for and injects 10～20% of total amount.
The Main Ingredients and Appearance of diverting agent can be polyacrylamide (being called for short PAM), acrylamide copolymer, its molecular weight ranges: 1,200 ten thousand～1,800 ten thousand, and degree of hydrolysis scope: 0～15%.The concentration range of polymer: 0.5～1.2%.
Crosslinking agent can be: arsenic (0.3～1.5%)-sodium sulfite (0.6～3%) system or phenolic aldehyde (0.1～0.8% phenol-0.1～0.8% aldehydes) system.
Water blockoff principal piece plug is the cross-linking system of host, wherein modified tannin extract concentration with the modified tannin extract: 3～12%; Crosslinker concentration: 0.5～4%; Assistant concentration: 0.2～1%.
Modified tannin extract is a larch extract, main component is the sulfonated products of tannin and non-tannis, sulfonation process can be introduced sulfonic group in the tannin molecule, tannin can be made of the former cyanidin of poly, the nucleophilic center of the A of flavanols unit ring C-6 or C-8 position in the molecule, under the catalysis of alkali, can react, form the methylene-bridged key with formaldehyde.
Sealing slug is to be the system of host with cement; Wherein cement factor is 15～25%, removes native content 2.5～4.7%, retarding agent 0.07～0.3%, and the temperature range that is suitable for is 20～300 ℃.
The invention has the advantages that: make the blocking agent selectivity enter water layer; Blocking agent the host high temperature resistant and anti-high salinity of energy also has long-term thermal stability; The plugged zone that forms has high pressure resistant formation water and washes away required intensity for a long time, thereby reach the moisture content that reduces high temperature and high salt oil deposit oil recovery later stage oil well, increase oil production, the purpose that reduces production costs is applicable to the modified tannin extract gel water-plugging of high temperature and high salt oil deposit.
Description of drawings
Fig. 1 becomes glue and broken glue time and temperature relation figure for injectant;
Fig. 2 becomes the relation of modulus of elasticity and frequency of oscillation behind the glue for injectant;
Fig. 3 is the influence of ageing time to blocking agent host intensity;
Fig. 4 is the rock core shutoff test (125 ℃) of 10%GKJ blocking agent;
Fig. 5 handles the production curve of front and back SH1104 well for shutoff.
Concrete enforcement
The oilwell water shutoff of high temperature and high salt oil deposit will run into following problem, and 1. blocking agent is essential steady in a long-term under the high temperature and high salt environment; 2. water-yielding stratum pressure causes the blocking agent major part of injection to enter oil reservoir greater than oil-producing formation pressure during oilwell water shutoff, causes stifled oil not water blockoff or the invalid phenomenon of shutoff; Even 3. form shutoff at the oil well water layer, plugged zone is generally the lower material of intensity, can't resist washing away for a long time of high pressure formation water, makes plugging material destroyed, and counter spuing.In order to solve an above-mentioned difficult problem, adopt three slugs to inject the water blockoff new technology, can increase substantially the success rate of high temperature and high salt oil deposit oilwell water shutoff.Wherein first slug is the diverting agent of selecting according to reservoir temperature, accounts for to inject 10～20% of total amount.Diverting agent injects back short time closing well waits with fixed attention, makes diverting agent become the temporarily stifled earlier oil reservoir of glue, allows second slug (the heavy dose of low viscosity blocking agent host colloidal sol) selectivity of follow-up injection enter water layer.The characteristics of this slug are low viscosity, easily inject, can form high viscoelastic gel under formation temperature, and suitable temperature range is 90～280 ℃, account for to inject 70～80% of total amount.Can formation have GKJ gel high temperature resistant, Heat stability is good, thereby obtain stable shutoff barrier.Thereafter the 3rd slug is a cement, as sealing compound, improves the intensity of shutoff principal piece plug, accounts for and injects 10～20% of total amount.1 diverting agent performance
The selection of diverting agent should be followed following principle: 1. colloidal sol promptly has viscosity higher does not influence injection again.Big more according to fluid viscosity, the easy more principle that enters the little seepage channel of flow resistance, diverting agent will mainly enter the low oil-producing formation of outflow pressure; And do not become glue before entering oil-producing formation.2. become glue as early as possible after entering oil-producing formation; 3. the gel of Xing Chenging has certain intensity, can stop the blocking agent principal piece of follow-up injection to enter oil-producing formation.4. become the fluid close behind the broken glue, easily discharge with oil/water with the viscosity of water.
The Main Ingredients and Appearance of diverting agent can be polyacrylamide (being called for short PAM), acrylamide copolymer etc., its molecular weight ranges: 1,200 ten thousand～1,800 ten thousand, and degree of hydrolysis scope: 0～15%.The concentration range of polymer: 0.5～1.2%.Crosslinking agent can be: arsenic (0.3～1.5%)-sodium sulfite (0.6～3%) system or phenolic aldehyde (0.1～0.8% phenol-0.1～0.8% aldehydes) system.For example: with 0.6% polyacrylamide is host, adds the system of arsenic-sodium thiosulfate, at 30 ℃, shear rate 5～95s
-1Down, the apparent viscosity of its colloidal sol is 850 ~ 590mPas.As can be known under 100 ℃～126 ℃, gelation time is about 30min～10min by the relation (Fig. 1) of the diverting agent gelation time of indoor measurement and temperature; If temperature is lower than 60 ℃, gelation time＞10h.There are two kinds of factors will delay into glue at the scene, oil field.Inject the water flushing pressure testing to 50MPa during first construction, clear water will make pit shaft and nearly well area cooling.It two is to flow to cause colloidal sol to postpone into glue (laboratory experiment proves).In order to satisfy above-mentioned using priciple as far as possible, when dosing, diverting agent is made into the A liquid and the B liquid that can not become glue, mix at well head then and inject.Behind the diverting agent slug, connect the notes displacement fluid, make it all to enter stratum and closing well and wait about 1h with fixed attention.Diverting agent can form aqueous gel (Fig. 2) the obstruction barrier of G ' near 10Pa under the formation temperature effect.The resistance that the blocking agent of follow-up injection enters oil reservoir increases widely, reaches the purpose that selectivity enters water layer.According to the relation (Fig. 1) of broken glue time of diverting agent and temperature, diverting agent is broken glueization behind 13～15h.In laboratory experiment, the product of the broken glueization of diverting agent gel is mainly the viscosity and the near aqueous solution of water, and polymer is wherein almost completely degraded, and will flow out in the back that drives a well again.2 blocking agent performances
Water blockoff principal piece plug is the cross-linking system of host with modified tannin extract (being called for short GKJ).Modified tannin extract concentration wherein: 3～12%; Crosslinker concentration: 0.5～4%; Assistant concentration: 0.2～1%.Modified tannin extract is the sulfonated products of larch extract (main component is tannin and non-tannis), and sulfonation process is mainly introduced sulfonic group in the tannin molecule, thereby improves the water-soluble and salt tolerance of product.The crosslinked ability of GKJ depends on contained tannin molecule.Tannin mainly is made of the former cyanidin of poly, and the nucleophilic center of the A of flavanols unit ring C-6 or C-8 position can react with formaldehyde under the catalysis of alkali in the molecule, forms the methylene-bridged key.Flavanols unit B ring (catechol type) is active not as good as the A ring, only just participates in cross-linking reaction under the catalysis of high pH
[6]
With 10% modified tannin extract (be called for short GKJ) be that the apparent viscosity of colloidal sol under 30 ℃ of blocking agent host is about 4.7～5.4mPas, is easy to injection.According to gelation time and temperature relation (Fig. 1), about 2～3h can become glue under 126 ℃.Be subjected to influence mobile and that colloidal sol heats up in oil well, actual gelation time should be greater than 5h.The gelation time of modified tannin extract cross-linking system can be regulated by changing pH and adding retarding agent
[3], should be able to become glue as early as possible after the cross-linking system that is used for water blockoff enters the stratum, in order to avoid by too towards rare.The elastic modulus G ' of blocking agent gel can reach 10000Pa above (Fig. 2) behind the one-tenth glue, forms viscoplasticity and stops up barrier.This barrier can omit deformation under the effect of pressure, the effect that is similar to cork is arranged in the stratum, effectively the shutoff water stream channel.
Blocking agent host gel 125 ℃ down aging, modulus of elasticity curve (Fig. 3) over time illustrate and wears out the heat stability height of modified tannin extract gel behind the 100d that the modulus of elasticity of gel and face shaping are constant substantially.3 sealing compound performances
Sealing slug is to be the system of host with cement; Wherein cement factor is 15～25%, removes native content 2.5～4.7%, retarding agent 0.07～0.3%, and the temperature range that is suitable for is 20 ~ 300 ℃.
Its initial apparent viscosity of the sealing compound cement paste that constitutes with 20% cement is about 20mPas.Under 100～130 ℃, the thickening time is 12 ~ 20h, and the elastic modulus G ' of solidifying back cement forms high-intensity sealing layer up to 1000000Pa (Fig. 2), guarantees that plugged zone can not released by high-pressure fluid is counter.Embodiment 1: laboratory core shutoff test
Under 125 ℃, adopt the 10%GKJ blocking agent that the square rock core of glued quartz sand free from flaw cylinder rock core and glued quartz sand crack has been carried out the shutoff test, the results are shown in Table 1 and Fig. 4.
Water phase permeability (the K of free from flaw rock core
W) be 1870.95 * 10
-3μ m
2, it is 0.011MPa that colloidal sol injects equilibrium pressure, resistance coefficient (F
r) be 25.At 125 ℃ of following constant temperature 5d, with the Darcy velocity displacement rock core of formation water with 0.879m/d, recording breakthrough pressure is 0.44MPa/cm, residual resistance factor (F
Rr1) be 24000, almost by complete shutoff, permeability reduces to 0.08 * 10 to rock core
-3μ m
2It is aging to continue constant temperature, residual resistance factor (F behind the 28d
Rr2) be 20000, the heat stability height of blocking agent is described, plugged zone is not destroyed.
The matrix permeability of crack rock core is 70 * 10
-3μ m
2, the centre is the thick coarse sand interlayer of 0.3cm, is 9230 * 10 with the average water phase permeability of measuring behind the rock core of water saturation crack, stratum
-3μ m
2It is 0.0047MPa that colloidal sol injects equilibrium pressure, resistance coefficient (F
r) be 16.2.Recording breakthrough pressure behind 125 ℃ of following constant temperature 5d is 0.048MPa/cm, residual resistance factor (F
Rr) be 7200, the crack is by effectively shutoff, and mean permeability reduces to 0.38 * 10
-3μ m
2, reduced the percolation ability of crack rock core significantly.Embodiment 2 Shi Xi oil field Carboniferous System deep-well bottom water plugging field trials
Carried out the site operation of the Shi Xi oil field Carboniferous System deep-well bottom water plugging October 27 calendar year 2001.The master data of SH1104 well sees Table 2 and since stable yields nearly 3 years, underground movable oil mass may be few.At this well water flood seriously, the big problem that may cause blocking agent host to be difficult for entering water layer of discharge pressure, adopt diverting agent-modified tannin extract blocking agent principal piece plug-cement to seal the special shutoff mode of slug.Expectation energy shutoff water stream channel, the economic exploitation phase of prolongation oil well.
In construction, at first carry out sleeve pipe and put pressure, stop after seeing liquid.Connect pipeline then, pressure testing 50MPa does not sting and does not leak for qualified.Injection process comprises: 1. diverting agent 20m
32. insulating liquid (clear water) 15m
33. closing well is waited and was coagulated 1 hour; 4. modified tannin extract 100m
35. cement 13m
36. displacement fluid (clear water) 20m
3(oil pipe injects 15m
3, sleeve pipe injects 5m
3).Injection rate is 0.3～0.6m
3/ min, and keep squeeze pressure＜52MPa, closing well is waited and is driven a well after 5 days with fixed attention again.Fig. 5 is the production The dynamic monitor result before and after the shutoff of SH1104 well is handled.In 3 wheat harvesting periods after shutoff is handled, the per day production fluid of this well is reduced to 92t, per day produce oil increases to 13.4t and per day moisture content reduces to 85%.With compare before the water blockoff, day volume increase crude oil 4～8t, moisture content descends 6%～10%, but being apparent that daily fluid production rate most from producing performance graph, changing.Keep at oil pressure that constant substantially (19 ± 1MPa), its reduction amplitude increases gradually, and the 105t before shutoff reduces to the 81t of shutoff after 3 months.And still on a declining curve so far, its reason may be to have changed former Φ 3.5mm oil nozzle into Φ 4.0mm oil nozzle when driving a well again to produce, and causes initial stage production fluid amount bigger, gains the oil nozzle into Φ 3.5mm afterwards again, makes production fluid measure the existing phenomenon that descends gradually.
About 120,000 yuan altogether of the chemical agent of guiding test this time and build costs.In 3 months, the crude oil increment is about 400t after the shutoff.Disregard the benefit that the production fluid amount reduces, chemical agent input/have a net increase of crude oil output=1/3.33.Test this time have a net increase of one of not high reason of former oil mass be the SH1104 well stable yields crude oil (60t/d) for many years, underground movable oil mass has limit, the water logging time is longer again.Even so, site test results also show employing diverting agent-modified tannin extract blocking agent principal piece plug-cement seal slug to deep-well high temperature at the bottom of the shutoff of water obtained breakthrough first, significant.
According to plug agent amount (Q) and theoretical blocking radius (R) relational expression: Q=π R
2H Φ (wherein h is that processing layer thickness 16m, Φ are average pore 0.1322), calculating R only is 4.12m.This value may be too small for the SH1104 well of water water awl at the bottom of the high temperature, so that can not block aquaporin fully.If suitably strengthen the chemical agent injection rate during construction, may obtain better effect.
Table 1 is under 125 ℃, and the GKJ gel is to 125 ℃ of the shutoff result of the test Table1 The plugging test results of consolidating quartz sandstone cores with GKJ gel in of glued quartz sand rock core
The square crack of the cylindric rock core of parameter free from flaw rock core
Rock core size (cm) 8.067 * Φ 2.512 19.6 * 3.5 * 3.5
Degree of porosity (%) 27.26 29.03
Water phase permeability K
w(10
-3μ m
2) 1871.0 9230
Formation water injection pressure (MPa) 4.4 * 10
-42.9 * 10
-4
Resistance coefficient F
r25 16.2
Residual resistance factor F behind the one-tenth glue 5d
Rr124,000 7200
Residual resistance factor F behind the one-tenth glue 28d
Rr220000-
Breakthrough pressure (MPa/cm) 0.44 0.048
Water phase permeability (10 after the shutoff
-3μ m
2) 0.08 0.38
Table 2 SH1104 well master data
Table2?The?basic?data?in?well?SH1104
Parameter values
Artificial bottom of a well (m) 4446.6
Present shaft bottom (m) 4329.44
Cementing quality is defective
Production string (mm) Φ 139.7
Oil pipe (the Φ 73 * 4248.95 of mm * m)
Down-hole string structure Φ 54mm horn mouth
Oil reservoir layer position C
Perforated interval I thickness (m) 4264.0～4260.0
Perforated interval II thickness (m) 4274.0～4270.0
Perforated interval III thickness (m) 4286.0～4278.0
Claims (6)
1. be applicable to the modified tannin extract gel water-plugging technique of high temperature and high salt oil deposit, it is characterized in that: adopt three slugs to inject water blockoff, first slug is: diverting agent such as, it accounts for and injects 10～20% of total amount, diverting agent inject the back 0.5～1.5h in the time closing well wait and coagulate; The heavy dose of low viscosity blocking agent of second slug host colloidal sol selectivity of follow-up injection is entered water layer, and it accounts for and injects 70～80% of total amount; Thereafter the 3rd slug is a cement, as sealing compound, accounts for and injects 10～20% of total amount.
2. the modified tannin extract gel water-plugging technique that is applicable to high temperature and high salt oil deposit according to claim 1, it is characterized in that: the Main Ingredients and Appearance of diverting agent can be polyacrylamide, acrylamide copolymer, its molecular weight ranges: 1,200 ten thousand～1,800 ten thousand, degree of hydrolysis scope: 0～15%.The concentration range of polymer: 0.5～1.2%.
3. the modified tannin extract gel water-plugging technique that is applicable to high temperature and high salt oil deposit according to claim 1, it is characterized in that: crosslinking agent can be: arsenic (0.3～1.5%)-sodium sulfite (0.6～3%) system or phenolic aldehyde (0.1～0.8% phenol-0.1～0.8% aldehydes) system.
4. the modified tannin extract gel water-plugging technique that is applicable to high temperature and high salt oil deposit according to claim 1 is characterized in that: water blockoff principal piece plug is the cross-linking system of host, wherein modified tannin extract concentration with the modified tannin extract: 3～12%; Crosslinker concentration: 0.5～4 %; Assistant concentration: 0.2～1%.
5. the modified tannin extract gel water-plugging technique that is applicable to high temperature and high salt oil deposit according to claim 4, it is characterized in that: modified tannin extract is a larch extract, main component is the sulfonated products of tannin and non-tannis, sulfonation process can be introduced sulfonic group in the tannin molecule, tannin can be made of the former cyanidin of poly, the nucleophilic center of the A of flavanols unit ring C-6 or C-8 position can react with formaldehyde under the catalysis of alkali in the molecule, forms the methylene-bridged key.
6. the modified tannin extract gel water-plugging technique that is applicable to high temperature and high salt oil deposit according to claim 1 is characterized in that: sealing slug is to be the system of host with cement; Wherein cement factor is 15～25%, removes native content 2.5～4.7%, retarding agent 0.07～0.3%, and the temperature range that is suitable for is 20～300 ℃.
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| CN 02121291 CN1464173A (en) | 2002-06-14 | 2002-06-14 | Modified tannin extract gel water plugging technology suitable for high-temperature high-salt oil reservoir |
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