CN105735956A - Hot fluid injection blockage relieving and production increasing process for immovable string - Google Patents
Hot fluid injection blockage relieving and production increasing process for immovable string Download PDFInfo
- Publication number
- CN105735956A CN105735956A CN201610094578.7A CN201610094578A CN105735956A CN 105735956 A CN105735956 A CN 105735956A CN 201610094578 A CN201610094578 A CN 201610094578A CN 105735956 A CN105735956 A CN 105735956A
- Authority
- CN
- China
- Prior art keywords
- fluid injection
- fluid
- hot
- pressure
- injection
- 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 102
- 238000002347 injection Methods 0.000 title claims abstract description 87
- 239000007924 injection Substances 0.000 title claims abstract description 87
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 57
- 238000000034 method Methods 0.000 title claims abstract description 33
- 230000008569 process Effects 0.000 title abstract description 9
- 230000001965 increasing effect Effects 0.000 title abstract description 8
- 238000007664 blowing Methods 0.000 claims abstract description 33
- 239000007788 liquid Substances 0.000 claims abstract description 6
- 238000002513 implantation Methods 0.000 claims description 29
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 26
- 230000000638 stimulation Effects 0.000 claims description 19
- 238000011084 recovery Methods 0.000 claims description 17
- 229910052757 nitrogen Inorganic materials 0.000 claims description 12
- 238000005086 pumping Methods 0.000 claims description 12
- 239000007789 gas Substances 0.000 claims description 8
- 239000003129 oil well Substances 0.000 claims description 7
- 230000009467 reduction Effects 0.000 claims description 7
- 238000002474 experimental method Methods 0.000 claims description 6
- 230000007246 mechanism Effects 0.000 claims description 6
- 230000033228 biological regulation Effects 0.000 claims description 5
- 230000000740 bleeding effect Effects 0.000 claims description 4
- 230000035945 sensitivity Effects 0.000 claims description 4
- 238000000605 extraction Methods 0.000 abstract 1
- 238000002791 soaking Methods 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 43
- 230000000694 effects Effects 0.000 description 13
- 238000013461 design Methods 0.000 description 7
- 239000004576 sand Substances 0.000 description 7
- 230000008859 change Effects 0.000 description 6
- 238000000151 deposition Methods 0.000 description 4
- 230000008021 deposition Effects 0.000 description 4
- 230000005284 excitation Effects 0.000 description 4
- 230000000007 visual effect Effects 0.000 description 4
- 230000008901 benefit Effects 0.000 description 3
- 238000004364 calculation method Methods 0.000 description 3
- 239000000295 fuel oil Substances 0.000 description 3
- 238000001802 infusion Methods 0.000 description 3
- 239000000126 substance Substances 0.000 description 3
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- 229910000831 Steel Inorganic materials 0.000 description 2
- 239000010620 bay oil Substances 0.000 description 2
- 239000000084 colloidal system Substances 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 229910001873 dinitrogen Inorganic materials 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 239000010959 steel Substances 0.000 description 2
- 238000004458 analytical method Methods 0.000 description 1
- 239000010426 asphalt Substances 0.000 description 1
- 238000000429 assembly Methods 0.000 description 1
- 230000000712 assembly Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 230000036772 blood pressure Effects 0.000 description 1
- 229910002092 carbon dioxide Inorganic materials 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 238000006731 degradation reaction Methods 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 238000002372 labelling Methods 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
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)
- Meat, Egg Or Seafood Products (AREA)
Abstract
The invention discloses a hot fluid injection blockage relieving and production increasing process for an immovable string. Hot fluid is injected into a stratum through thickened oil extraction equipment, and then well soaking, blowing and pump exhausting and production are conducted. According to the provided hot fluid injection blockage relieving and production increasing process for the immovable string, the operation cycle can be greatly shortened, the operation cost can be greatly reduced, pump starting and production can be timely conducted according to the condition of the output ratio of liquid, gas and oil during blowing, and the situation that the heat injection and production increasing effect is influenced due to operation of a movable string is avoided.
Description
Technical field
Present document relates to but be not limited to oil exploration equipment technology, espespecially a kind of fixed tubular column hot-fluid injection plugging removal and stimulation technique.
Background technology
Bohai Bay Oil heavy oil reserves is enriched, and is divided into the general I class viscous crude of viscosity of crude 50～150mPa s, the general II class viscous crude of viscosity of crude 150～10000mPa s and the viscosity of crude special thick oil more than 10000mPa s, and heavy oil reserves accounts for more than the 70% of gross reserves.
The viscous crude of current Bohai Bay Oil general I class 50～150mPa s and the viscous crude of general II class 150～350mPa s are mainly taked cold to adopt mode development, developed by directional well, encrypted adjustment well, horizontal well, water drive and chemical flooding mode, but rate of oil production is low, recovery percent of reserves is low feature that general performance goes out, development effectiveness is not ideal enough, and individual well operation initial productivity is higher.Due to colloid, asphalt content height in viscous crude, viscosity of crude is higher, poor fluidity, easily flocculate formation of deposits organic deposition near wellbore zone, and along with the reduction of temperature in wellbore, organic deposition is piled up at tube inner wall and Pump Suction Nozzle, cause oil pipe undergauge and electric submersible pump blocking, cause oil well low yield poor efficiency；Single well controlled reserves is high, but recovery percent of reserves low (being generally 1%-8%), potentiality of taping the latent power are big.Pit shaft and near wellbore zone organic plugging problem have had a strong impact on the production effect of common heavy oil well, need solution badly.
Summary of the invention
In order to solve at least one in above-mentioned technical problem, there is provided herein a kind of fixed tubular column hot-fluid injection plugging removal and stimulation technique, duty cycle can be greatly shortened and reduce operating cost, during blowing, visual production fluid gas-oil ratio situation opens pump production in good time, it is to avoid dynamic tubing string j ob impact heat injection effect of increasing production.
In order to reach purpose herein, there is provided herein a kind of fixed tubular column hot-fluid injection plugging removal and stimulation technique, by thickened oil recovery equipment to heated fluid injection in stratum, then carry out stewing well, blowing and pump pumping and produce.
Alternatively, determining hot fluid injection channel according to flow string structure, install tree-protector and leak out danger reducing wellhead assembly thorn, before heated fluid injection, blowing turns pump pumping and produces and be all made without moving tubing string operation after terminating.
Alternatively, before heated fluid injection, calculate the maximum implantation temperature of the hot fluid of thickened oil recovery equipment and maximum injection pressure.
Alternatively, T is adoptedmax=0.85 × min{T1, T2, T3... TnDetermine the maximum implantation temperature of hot fluid (14), adopt Pmax=0.85 × min{P1, P2, P3... PnDetermine the maximum injection pressure of hot fluid (14)；Wherein, TmaxThe maximum implantation temperature of-well head, DEG C；0.85-safety coefficient；T1,T2,T3,……Tn-well head the implantation temperature that obtains according to each temperature sensitivity node inverse of production wellhead and down-hole, DEG C；PmaxThe maximum implantation temperature of-well head, DEG C；0.85-safety coefficient；P1,P2,P3,……Pn-the well intake pressure that obtains according to each pressure sensibility node inverse of well head and down-hole, MPa.
Alternatively, by thickened oil recovery equipment to heated fluid injection in the viscous crude in stratum it is: gas supply device (7) is thermally shielded to nitrogen injection in the annular space between flow string (1) and sleeve pipe (6) by sleeve pipe flutter valve (5)；Then hot fluid feeding mechanism (2) is by flow string (1) and sliding sleeve (8) to heated fluid injection in stratum (14), and the implantation temperature of hot fluid (14) is not more than Tmax, injection pressure be not more than Pmax。
Alternatively, stewing well terminates rear oil well and first carries out blowing production, and during blowing, annular pressure reduction speed is not more than 50psi/min, stops bleeding off pressure, pressurize 15～30min when annular pressure is reduced to the half of initial pressure；Carry out opening pump when blowing production gas-oil ratio is down to 30%～50% again to produce.
Alternatively, during blowing and pump pumping are produced, the mode that promotes step by step is taked in the regulation and control of production fluid speed, and most high yield liquid limit valueWherein, ViThe sanding critical flow velocity that-experiment obtains, m3/d；D-experiment core diameter, m；D-horizontal segment screen casing diameter, m；L-horizontal section length, m；The critical production fluid speed of Q-oil well, m3/d。
Compared with prior art, fixed tubular column hot-fluid injection plugging removal and stimulation technique provided herein, duty cycle can being greatly shortened and reduce operating cost, during blowing, visual production fluid gas-oil ratio situation opens pump production in good time, it is to avoid dynamic tubing string j ob impact heat injection effect of increasing production.
Fixed tubular column hot-fluid injection de-plugging process described herein, it is first determined rationally hot fluid injection channel, then installs tree-protector and carries out the injection operation of motionless flow string, and injection rate is stewing well, blowing and pump pumping product after reaching design load.This technique is taked to install tree-protector reduction wellhead assembly and is stung danger of leaking out；Optimize well head implantation temperature and pressure, while ensureing well bore and downhole safety, improve injection parameter, to ensure plugging removal and stimulation effect as far as possible；Staged method of adjustment is taked in production process production fluid and pressure change, it is to avoid stratum excitation is shaked out and protects cable of electric submersible pump.This technique can not only maximize guarantee hot-fluid injection plugging removal and stimulation effect, job safety risk and workload, saving operating cost can be greatly lowered simultaneously.
Further feature herein and advantage will be set forth in the following description, and, partly become apparent from description, or understand by implementing this paper.Purpose herein and other advantages can be realized by structure specifically noted in description, claims and accompanying drawing and be obtained.
Accompanying drawing explanation
Accompanying drawing is for providing being further appreciated by this paper technical scheme, and constitutes a part for description, for explaining technical scheme herein together with embodiments herein, being not intended that the restriction to this paper technical scheme.
Fig. 1 is the structural representation of the thickened oil recovery equipment described in one embodiment of the application.
Wherein, in Fig. 1, corresponding relation between accompanying drawing labelling and component names is:
1 flow string, 2 hot fluid feeding mechanisms, 3 oil pipe flutter valves, 4 wellhead assemblies, 5 sleeve pipe flutter valves, 6 sleeve pipes, 7 gas supply devices, 8 sliding sleeves, 9 electric submersible pumps, 10 packers, 11 sand control screens, 12 tree-protectors, 13 nitrogen, 14 hot fluids, 15 oil reservoirs, 16 organic depositions.
Detailed description of the invention
For making purpose herein, technical scheme and advantage clearly understand, below in conjunction with accompanying drawing, the embodiments herein is described in detail.It should be noted that when not conflicting, the embodiment in the application and the feature in embodiment can combination in any mutually.
Elaborate a lot of detail in the following description so that fully understanding herein, but, other can also be adopted to be different from mode described here herein and implement, therefore, protection domain herein is not by the restriction of following public specific embodiment.
Thickened oil recovery equipment and the fixed tubular column hot-fluid injection de-plugging process of some embodiments herein are described below in conjunction with accompanying drawing.
The thickened oil recovery equipment that an embodiment adopts herein, as it is shown in figure 1, include: flow string 1；Hot fluid feeding mechanism 2, for supplying hot fluid 14 in flow string 1；Oil pipe flutter valve 3, is arranged on the top of wellhead assembly 4 and is connected with flow string 1；Wellhead assembly 4, is positioned at flow string 1 and the top of sleeve pipe 6；Sleeve pipe flutter valve 5, is positioned at the bottom of wellhead assembly 4 and is connected with sleeve pipe 6；Sleeve pipe 6, is positioned at the outside of the lower section of sleeve pipe flutter valve 5, flow string 1；Gas supply device 7, for supplying gas in sleeve pipe 6；Sliding sleeve 8, is positioned at the lower section of sleeve pipe flutter valve 5 and is arranged on flow string 1；Electric submersible pump 9, is positioned at the lower section of sliding sleeve 8 and is arranged on flow string 1；Packer 10 and sand control screen 11, be arranged on the bottom of sleeve pipe 6.
Thickened oil recovery equipment provided herein, it is possible to duty cycle is greatly shortened and reduces operating cost, during blowing, visual production fluid gas-oil ratio situation opens pump production in good time, it is to avoid dynamic tubing string j ob impact heat injection effect of increasing production.
Label 16 is the organic deposition 16 on flow string 1 inwall.
Alternatively, thickened oil recovery equipment also includes: tree-protector 12, is positioned at the top of wellhead assembly 4 and connects flow string 1.
Owing to wellhead assembly bears injection maximum temperature, pressure, security risk is big, installs tree-protector and hot fluid can be avoided directly to contact wellhead assembly 4, is substantially reduced wellhead assembly and stings danger of leaking out.
Alternatively, the supply opening of hot fluid feeding mechanism 2 can be connected with the upper end open of flow string 1, to supply hot fluid 14 in flow string 1.
Alternatively, the air supply opening of gas supply device 7 can be connected with sleeve pipe flutter valve 5, to supply gas in the annular space between sleeve pipe 6 and flow string 1, such as highly purified nitrogen, carbon dioxide etc..
The fixed tubular column hot-fluid injection plugging removal and stimulation technique that the application provides, by thickened oil recovery equipment to heated fluid injection in stratum 14, then carries out stewing well, blowing and pump pumping and produces.
Fixed tubular column hot-fluid injection de-plugging process described herein, it is first determined rationally hot fluid injection channel, then installs tree-protector and carries out the injection operation of motionless flow string, and injection rate is stewing well, blowing and pump pumping product after reaching design load.This technique is taked to install tree-protector reduction wellhead assembly and is stung danger of leaking out；Optimize well head implantation temperature and pressure, while ensureing well bore and downhole safety, improve injection parameter, to ensure plugging removal and stimulation effect as far as possible；Staged method of adjustment is taked in production process production fluid and pressure change, it is to avoid stratum excitation is shaked out and protects cable of electric submersible pump.This technique can not only maximize guarantee hot-fluid injection plugging removal and stimulation effect, job safety risk and workload, saving operating cost can be greatly lowered simultaneously.
Alternatively, the preparation before heated fluid injection 14 includes:
1, hot fluid injection channel is determined
Analyze target well flow string structure, to improve shaft bottom implantation temperature be target, to ensure that job safety is for principle, it is determined that fluid infusion channel.For Y type flow string, either directly through oil pipe, hot fluid can be injected stratum；For non-Y type flow string, being opened by production sliding sleeve by steel wire operation, hot fluid enters oil jacket annular space injection stratum by producing sliding sleeve.
2, tree-protector is installed
Owing to wellhead assembly bears injection maximum temperature, pressure, security risk is big, installs tree-protector and hot fluid can be avoided directly to contact well head, is substantially reduced wellhead assembly and stings danger of leaking out.
Alternatively, before heated fluid injection 14, first calculate the maximum implantation temperature of the hot fluid 14 of thickened oil recovery equipment and maximum injection pressure.
Ensure heat injection plugging removal effect for maximizing, reduce operating risk simultaneously, need analysis measures well solid completion system (cementing concrete, sand control pipe, top packer etc.), down-hole string/instrument (oil pipe, storm valve, cable-passing packer, liquid controling pipe line etc.), hoisting system (electric pump, pump condition, cable etc.) heat resisting and pressure resisting performance parameter, so that it is determined that the work of each security of system lower maximum implantation temperature of well head, pressure.
Wherein, T is adoptedmax=0.85 × min{T1, T2, T3... TnDetermine the maximum implantation temperature of hot fluid 14, adopt Pmax=0.85 × min{P1, P2, P3... PnDetermine the maximum injection pressure of hot fluid 14；Wherein, TmaxThe maximum implantation temperature of-well head, DEG C；0.85-safety coefficient；T1,T2,T3,……Tn-well head the implantation temperature that obtains according to each temperature sensitivity node inverse of production wellhead and down-hole, DEG C；PmaxThe maximum implantation temperature of-well head, DEG C；0.85-safety coefficient；P1,P2,P3,……Pn-the well intake pressure that obtains according to each pressure sensibility node inverse of well head and down-hole, MPa.
Alternatively, by thickened oil recovery equipment to heated fluid injection in the viscous crude in stratum it is: gas supply device 7 is thermally shielded to nitrogen injection 13 in the annular space between flow string 1 and sleeve pipe 6 by sleeve pipe flutter valve 5；Then hot fluid feeding mechanism 2 passes through flow string 1 and sliding sleeve 8 to heated fluid injection in stratum 14, and the implantation temperature of hot fluid 14 is not more than Tmax, injection pressure be not more than Pmax。
Particularly as follows:
1. " nitrogen injects
Injecting high-purity nitrogen by sleeve pipe flutter valve to (that is: in the annular space between flow string and sleeve pipe) in oil jacket annular space to be thermally shielded, nitrogen gas purity, more than 99.9%, is full of after nitrogen until annular space, carries out step 2.；
2. hot fluid injects
Control implantation temperature and be not more than Tmax, control injection pressure and be not more than Pmax, stop injecting after fluid injection rate reaches design load.
Alternatively, during blowing and pump pumping are produced, stewing well terminates rear oil well and first carries out blowing production, and during blowing, annular pressure reduction speed is not more than 50psi/min, stops bleeding off pressure, pressurize 15～30min when annular pressure is reduced to the half of initial pressure；Carry out opening pump when blowing production gas-oil ratio is down to 30%～50% again to produce, should strictly control production fluid and pressure change in blowing and electric submersible pump production period.
Alternatively, during blowing and pump pumping are produced, the mode that promotes step by step is taked in the regulation and control of production fluid speed, and most high yield liquid limit valueWherein, ViThe sanding critical flow velocity that-experiment obtains, m3/d；D-experiment core diameter, m；D-horizontal segment screen casing diameter, m；L-horizontal section length, m；The critical production fluid speed of Q-oil well, m3/d。
For preventing stratum excitation from shaking out, ensureing surface production flow process, target well blowing and electric submersible pump production initial stage should strictly control production fluid speed, and wherein most high yield liquid limit value need to be obtained by laboratory core displacement simulation experimental calculation, sees formulaAnd the regulation and control of production fluid speed should take the mode that slowly promotes step by step, it is to avoid production fluid is widely varied.
Wherein, pressure change control is:
The blowing initial stage, strict control annular pressure decrease speed, it is to avoid cable of electric submersible pump performance is impacted, takes following control measure:
A) annular pressure reduces speed less than 50psi/min, stops bleeding off pressure when being reduced to the half of initial pressure；
B) pressurize 15～30min；
Continue blood pressure lowering, repeat step a.
One specific embodiment of the application, as shown in Figure 1, oil reservoir is tiltedly 2639m deeply, the vertical thickness of oil reservoir 15 is 40.9m, ground viscosity of crude is 3047mPa s, wellhead assembly heatproof 120 DEG C, pressure 21MPa, cementing concrete G level, heatproof 110 DEG C, well-case perforating completion, perforation layer position 1971.9～2178.9m, perforation length 207m, sand control method is that high-quality screen casing adds gravel filling, storm valve heatproof 150 DEG C, pressure 35MPa, production packer heatproof 168 DEG C, pressure 35MPa, electric submersible screw pump produces, screw pump and downhole cable heatproof 120 DEG C, pressure 17MPa.Day at operation initial stage oil-producing 168m3, current day oil-producing 13m3/ d, moisture 14.4%.This well flowing bottomhole pressure (FBHP) declines, and producing pressure differential increases, and thinks that colloid/asphaltene deposits causes near wellbore zone organic plugging.
Fixed tubular column heat injection de-plugging process implemented by this well, and it comprises the steps:
1, fluid infusion channel is determined.
This well is common commingled column, and screw pump produces, and fluid can not be injected by screw pump.Being provided with sliding sleeve on this well well depth 836m place flow string, before heat injection, opened by sliding sleeve by steel wire operation, fluid enters oil jacket annular space by sliding sleeve and injects.Both reduced wellbore heat loss, improved shaft bottom implantation temperature, turn avoid infusion and enter the infringement to screw pump.
2, the maximum implantation temperature of well head and pressure are calculated.
Adopt specialty wellbore parameters software for calculation, according to each sensitivity node heatproof, pressure performance, inverse well head implantation temperature, injection pressure, finally determine TmaxIt is 113 DEG C, PmaxFor 14MPa.
Owing to this well wellhead assembly, screw pump etc. are gone into operation for many years, there is performance degradation catabiosis, directly implement heat injection operation, implantation temperature, injection pressure are limited, and there is security risk, should take necessary safeguard procedures.
3, tree-protector is installed.
Open tree cap, tree-protector is installed.Tree-protector heatproof 200 DEG C, pressure 25MPa, meet heat injection parameter request, reduces well head and stings danger of leaking out.
4, heated fluid injection.
It is continuously injected into high-purity nitrogen by sleeve pipe flutter valve to the annular space between flow string and sleeve pipe to be thermally shielded, notes nitrogen speed 300～500Nm3/ h, nitrogen gas purity is more than 99.9%, and injected slurry volume is depending on oil jacket annular volume and injection pressure.
Annular space starts to inject multielement hot fluid after being full of nitrogen.Multielement hot fluid reaches oil jacket annular space through tree-protector, flow string, sliding sleeve, controls implantation temperature and is not more than Tmax, control injection pressure and be not more than Pmax.This well design injection rate 1500t, stops injecting after reaching design injection rate.
The nitrogen that multielement hot fluid and annular space inject mixes in producing well shaft bottom, injects oil reservoir 15 through sand control screen.
5, stewing well.
When, after complete design injection rate, stopping injecting multielement hot fluid, close oil pipe flutter valve and sleeve pipe flutter valve, stewing well 1d.
6, blowing and pump pumping produce system control.
After stewing well terminates, the blowing that drives a well produces.
According to production fluid speed calculation formula, obtaining the highest production fluid speed of this well is 123m3/d.The blowing initial stage should strictly control production fluid speed, and the regulation and control of production fluid speed should take the slow mode promoted step by step, slowly regulates to 24m by controlling oil nozzle3/ d, observes 48 hours, and chemical examination is heightened to 48m gradually without after sand3/ h, observes 48 hours, depending on chemical examination containing sand situation the rest may be inferred adjust production fluid speed.When production gas-oil ratio is less than 30%, starts screw pump (electric submersible pump) and produce.
Qmax=VFace*A2* H=0.88*0.6783*207=123m3/d
Blowing produces the initial stage, and controlling annular pressure decrease speed is 50psi/min (0.34MPa/min), and pressurize 30min during pressure drop by half, until pressure stability, to ensure cable performance.
Start electric submersible pump during production gas-oil ratio 30% to produce.Adopt with note twice compared with tubing string this well operations reduce workover treatment time more than 8d, save operating cost more than 500,000 yuan, this well average day oil-producing reach 48m3/ d, effect duration super 200d, the tired oil that increases reach 5400m3。
In sum, thickened oil recovery equipment provided herein, it is possible to duty cycle is greatly shortened and reduces operating cost, during blowing, visual production fluid gas-oil ratio situation opens pump production in good time, it is to avoid dynamic tubing string j ob impact heat injection effect of increasing production.
Fixed tubular column hot-fluid injection de-plugging process described herein, it is first determined rationally hot fluid injection channel, then installs tree-protector and carries out the injection operation of motionless flow string, and injection rate is stewing well, blowing and pump pumping product after reaching design load.This technique is taked to install tree-protector reduction wellhead assembly and is stung danger of leaking out；Optimize well head implantation temperature and pressure, while ensureing well bore and downhole safety, improve injection parameter, to ensure plugging removal and stimulation effect as far as possible；Staged method of adjustment is taked in production process production fluid and pressure change, it is to avoid stratum excitation is shaked out and protects cable of electric submersible pump.This technique can not only maximize guarantee hot-fluid injection plugging removal and stimulation effect, job safety risk and workload, saving operating cost can be greatly lowered simultaneously.
In description herein, term " installation ", " being connected ", " connection ", " fixing " etc. all should be interpreted broadly, for instance, " connection " can be fixing connection, it is also possible to is removably connect, or connects integratedly；Can be joined directly together, it is also possible to be indirectly connected to by intermediary.For the ordinary skill in the art, it is possible to understand above-mentioned term concrete meaning in this article as the case may be.
In the description of this specification, specific features, structure, material or feature that the description of term " embodiment ", " some embodiments ", " specific embodiment " etc. means in conjunction with this embodiment or example describe are contained at least one embodiment herein or example.In this manual, the schematic representation of above-mentioned term is not necessarily referring to identical embodiment or example.And, the specific features of description, structure, material or feature can combine in an appropriate manner in any one or more embodiments or example.
Although embodiment disclosed herein is as above, but described content is only and readily appreciates the embodiment adopted herein, is not limited to herein.Technical staff in any this paper art; under the premise without departing from spirit and scope disclosed herein; any amendment and change can be carried out in the form implemented and details, but scope of patent protection herein, still must be as the criterion with the scope that appending claims defines.
Claims (7)
1. a fixed tubular column hot-fluid injection plugging removal and stimulation technique, it is characterised in that by thickened oil recovery equipment to heated fluid injection in stratum (14), then carries out stewing well, blowing and pump pumping and produces.
2. fixed tubular column hot-fluid injection plugging removal and stimulation technique according to claim 1, it is characterised in that determine hot fluid injection channel according to flow string structure, installs tree-protector.
3. fixed tubular column hot-fluid injection plugging removal and stimulation technique according to claim 1, it is characterised in that before heated fluid injection (14), calculates the maximum implantation temperature of the hot fluid (14) of thickened oil recovery equipment and maximum injection pressure.
4. fixed tubular column hot-fluid injection plugging removal and stimulation technique according to claim 2, it is characterised in that
Adopt Tmax=0.85 × min{T1, T2, T3... TnDetermine the maximum implantation temperature of hot fluid (14), adopt Pmax=0.85 × min{P1, P2, P3... PnDetermine the maximum injection pressure of hot fluid (14)；
Wherein, TmaxThe maximum implantation temperature of-well head, DEG C；0.85-safety coefficient；T1,T2,T3,……Tn-well head the implantation temperature that obtains according to each temperature sensitivity node inverse of production wellhead and down-hole, DEG C；PmaxThe maximum implantation temperature of-well head, DEG C；0.85-safety coefficient；P1,P2,P3,……Pn-the well intake pressure that obtains according to each pressure sensibility node inverse of well head and down-hole, MPa.
5. fixed tubular column hot-fluid injection plugging removal and stimulation technique according to claim 3, it is characterized in that, by thickened oil recovery equipment to heated fluid injection in the viscous crude in stratum be: gas supply device (7) is thermally shielded to nitrogen injection (13) in the annular space between flow string (1) and sleeve pipe (6) by sleeve pipe flutter valve (5)；Then hot fluid feeding mechanism (2) is by flow string (1) and sliding sleeve (8) to heated fluid injection in stratum (14), and the implantation temperature of hot fluid (14) is not more than Tmax, injection pressure be not more than Pmax。
6. fixed tubular column hot-fluid injection plugging removal and stimulation technique according to any one of claim 1 to 4, it is characterized in that, stewing well terminates rear oil well and first carries out blowing production, during blowing, annular pressure reduction speed is not more than 50psi/min, stop when annular pressure is reduced to the half of initial pressure bleeding off pressure, pressurize 15～30min；Carry out opening pump when blowing production gas-oil ratio is down to 30%～50% again to produce.
7. fixed tubular column hot-fluid injection plugging removal and stimulation technique according to claim 5, it is characterised in that during blowing and pump pumping are produced, the mode that promotes step by step is taked in the regulation and control of production fluid speed, and most high yield liquid limit value
Wherein, ViThe sanding critical flow velocity that-experiment obtains, m3/d；D-experiment core diameter, m；D-horizontal segment screen casing diameter, m；L-horizontal section length, m；The critical production fluid speed of Q-oil well, m3/d。
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610094578.7A CN105735956A (en) | 2016-02-19 | 2016-02-19 | Hot fluid injection blockage relieving and production increasing process for immovable string |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610094578.7A CN105735956A (en) | 2016-02-19 | 2016-02-19 | Hot fluid injection blockage relieving and production increasing process for immovable string |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN105735956A true CN105735956A (en) | 2016-07-06 |
Family
ID=56245437
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201610094578.7A Pending CN105735956A (en) | 2016-02-19 | 2016-02-19 | Hot fluid injection blockage relieving and production increasing process for immovable string |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN105735956A (en) |
Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107044273A (en) * | 2017-04-07 | 2017-08-15 | 中国石油大学(华东) | Sand control pit shaft blocks the integrated evaluation experimental analogue means of de-plugging and method |
| CN107218012A (en) * | 2017-07-27 | 2017-09-29 | 中国石油集团渤海钻探工程有限公司 | A kind of hot N of Oil/gas Well2De-plugging process method and device |
| CN110761761A (en) * | 2019-11-28 | 2020-02-07 | 中国海洋石油集团有限公司 | Method for reducing emulsification risk of thick oil in steam huff and puff process |
| CN115012892A (en) * | 2022-07-01 | 2022-09-06 | 中国海洋石油集团有限公司 | Technological method for injection-production integrated mining through electric pump throwing and fishing |
| CN115749759A (en) * | 2022-11-14 | 2023-03-07 | 东北石油大学 | Evaluation device and evaluation method for sand production rule of oil well fracturing shaft |
Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101161988A (en) * | 2006-10-09 | 2008-04-16 | 北京联众易盛石油开采新技术发展有限公司 | In situ combustion slug and steam driving combined type crude oil producing method |
| CN102678097A (en) * | 2012-05-24 | 2012-09-19 | 山东大学 | Supercritical water oxidation fluid injection production system using nitrogen as protective film and process using same |
| CN103122759A (en) * | 2013-01-28 | 2013-05-29 | 中国石油大学(华东) | Coal bed gas well multiple thermal fluid strengthening mining method |
| CN103867162A (en) * | 2014-03-25 | 2014-06-18 | 中国海洋石油总公司 | Thermal production well annulus thermal insulation system and method |
| CN104314541A (en) * | 2014-08-26 | 2015-01-28 | 中国海洋石油总公司 | Method for huff and puff mining of heavy oil reservoir through polybasic thermal fluid |
| CN104481483A (en) * | 2014-11-24 | 2015-04-01 | 中国石油天然气股份有限公司 | Heavy oil reservoir double-horizontal well SAGD middle and later period exploitation method |
| CN104912530A (en) * | 2015-03-07 | 2015-09-16 | 东营天华石油技术开发有限公司 | Continuous oil pipe underground multi-component thermal fluid generating device and implementing method |
-
2016
- 2016-02-19 CN CN201610094578.7A patent/CN105735956A/en active Pending
Patent Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101161988A (en) * | 2006-10-09 | 2008-04-16 | 北京联众易盛石油开采新技术发展有限公司 | In situ combustion slug and steam driving combined type crude oil producing method |
| CN102678097A (en) * | 2012-05-24 | 2012-09-19 | 山东大学 | Supercritical water oxidation fluid injection production system using nitrogen as protective film and process using same |
| CN103122759A (en) * | 2013-01-28 | 2013-05-29 | 中国石油大学(华东) | Coal bed gas well multiple thermal fluid strengthening mining method |
| CN103867162A (en) * | 2014-03-25 | 2014-06-18 | 中国海洋石油总公司 | Thermal production well annulus thermal insulation system and method |
| CN104314541A (en) * | 2014-08-26 | 2015-01-28 | 中国海洋石油总公司 | Method for huff and puff mining of heavy oil reservoir through polybasic thermal fluid |
| CN104481483A (en) * | 2014-11-24 | 2015-04-01 | 中国石油天然气股份有限公司 | Heavy oil reservoir double-horizontal well SAGD middle and later period exploitation method |
| CN104912530A (en) * | 2015-03-07 | 2015-09-16 | 东营天华石油技术开发有限公司 | Continuous oil pipe underground multi-component thermal fluid generating device and implementing method |
Non-Patent Citations (1)
| Title |
|---|
| 孙玉豹等: "《渤海油田多元热流体吞吐自喷期生产控制》", 《石油化工应用》 * |
Cited By (9)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107044273A (en) * | 2017-04-07 | 2017-08-15 | 中国石油大学(华东) | Sand control pit shaft blocks the integrated evaluation experimental analogue means of de-plugging and method |
| US10697277B2 (en) | 2017-04-07 | 2020-06-30 | China University Of Petroleum (East China) | Simulation device and method for integrated evaluation experiment for sand control wellbore plugging and plugging removal |
| CN107218012A (en) * | 2017-07-27 | 2017-09-29 | 中国石油集团渤海钻探工程有限公司 | A kind of hot N of Oil/gas Well2De-plugging process method and device |
| CN110761761A (en) * | 2019-11-28 | 2020-02-07 | 中国海洋石油集团有限公司 | Method for reducing emulsification risk of thick oil in steam huff and puff process |
| CN110761761B (en) * | 2019-11-28 | 2021-08-06 | 中国海洋石油集团有限公司 | Method for reducing emulsification risk of thick oil in steam huff and puff process |
| CN115012892A (en) * | 2022-07-01 | 2022-09-06 | 中国海洋石油集团有限公司 | Technological method for injection-production integrated mining through electric pump throwing and fishing |
| CN115012892B (en) * | 2022-07-01 | 2023-09-29 | 中国海洋石油集团有限公司 | Technological method for injection and production integrated exploitation through electric pump casting and dragging |
| CN115749759A (en) * | 2022-11-14 | 2023-03-07 | 东北石油大学 | Evaluation device and evaluation method for sand production rule of oil well fracturing shaft |
| CN115749759B (en) * | 2022-11-14 | 2023-09-05 | 东北石油大学 | Evaluation device and evaluation method for sand production rule of oil well fracturing shaft |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| US5450902A (en) | Method and apparatus for producing and drilling a well | |
| US5655605A (en) | Method and apparatus for producing and drilling a well | |
| CN103321622A (en) | Sand draining and oil extracting method in manner of integrating injection and extraction for thermal producing well and device thereof | |
| RU2206728C1 (en) | Method of high-viscocity oil production | |
| CN105735956A (en) | Hot fluid injection blockage relieving and production increasing process for immovable string | |
| US7422063B2 (en) | Hydrocarbon recovery from subterranean formations | |
| CN101089362B (en) | Improved steam huff and puff oil production method | |
| RU2363839C1 (en) | Procedure for development of high viscous oil deposits | |
| CN101855421A (en) | Heated fluid injection using multilateral wells | |
| CN101787854A (en) | Subsection well completion system of bottom water reservoir horizontal well | |
| CN202325428U (en) | Drive and let out compound oil recovery system | |
| CN102080522A (en) | Oil extraction method for oil deposit of shallow-layer super heavy oil | |
| CN114482955B (en) | Method for improving deep thickened oil extraction efficiency by utilizing downhole crude oil cracking modification | |
| CN201874543U (en) | Underground boosting water injection process pipe string | |
| RU2456441C1 (en) | Production method of high-viscous oil by means of simultaneous pumping of steam and extraction of liquid from single horizontal well | |
| CN110863808B (en) | A heavy oil recovery method with electric heating to enhance water flooding efficiency | |
| CN103470233B (en) | Heavy oil reservoir natural gas huff-puff oil production process system and oil production method | |
| US7980299B1 (en) | Horizontal well treating method | |
| CN203441440U (en) | Thickened oil recovery system for horizontal well | |
| CN208220728U (en) | Thick oil well pipe column | |
| CN204457702U (en) | SAGD horizontal well system | |
| EP3114309A1 (en) | Method for managing production of hydrocarbons from a subterranean reservoir | |
| RU2418162C1 (en) | Method for improving permeability of bed during extraction of high-viscosity oil | |
| RU2273729C1 (en) | Method for highly-viscous oil or bitumen deposit development | |
| CN203412561U (en) | Injection-production integrated sand-draining oil-producing device of thermal oil-producing well |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| C06 | Publication | ||
| PB01 | Publication | ||
| C10 | Entry into substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| CB02 | Change of applicant information |
Address after: 100010 Chaoyangmen North Street, Dongcheng District, Dongcheng District, Beijing Applicant after: China Offshore Oil Group Co., Ltd. Applicant after: China Oilfield Services Limited Address before: 100010 Chaoyangmen North Street, Dongcheng District, Dongcheng District, Beijing Applicant before: China National Offshore Oil Corporation Applicant before: China Oilfield Services Limited |
|
| CB02 | Change of applicant information | ||
| RJ01 | Rejection of invention patent application after publication |
Application publication date: 20160706 |
|
| RJ01 | Rejection of invention patent application after publication |