US20240229605A9 - Method for applying the scale inhibitor to completion fluids during injectivity test operations - Google Patents
Method for applying the scale inhibitor to completion fluids during injectivity test operations Download PDFInfo
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- US20240229605A9 US20240229605A9 US18/493,160 US202318493160A US2024229605A9 US 20240229605 A9 US20240229605 A9 US 20240229605A9 US 202318493160 A US202318493160 A US 202318493160A US 2024229605 A9 US2024229605 A9 US 2024229605A9
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- scale inhibitor
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- 239000012530 fluid Substances 0.000 title claims abstract description 62
- 239000002455 scale inhibitor Substances 0.000 title claims abstract description 36
- 238000012360 testing method Methods 0.000 title claims abstract description 34
- 238000000034 method Methods 0.000 title claims abstract description 19
- 238000004519 manufacturing process Methods 0.000 claims abstract description 27
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 15
- 239000011435 rock Substances 0.000 claims abstract description 11
- 238000005086 pumping Methods 0.000 claims description 22
- 239000013535 sea water Substances 0.000 claims description 11
- 150000001875 compounds Chemical class 0.000 claims description 8
- 238000012544 monitoring process Methods 0.000 claims description 8
- 239000003129 oil well Substances 0.000 claims description 7
- 238000004513 sizing Methods 0.000 claims description 3
- 230000003068 static effect Effects 0.000 claims description 3
- 230000002706 hydrostatic effect Effects 0.000 claims description 2
- 230000008901 benefit Effects 0.000 abstract description 6
- 238000011049 filling Methods 0.000 abstract description 2
- 239000003112 inhibitor Substances 0.000 description 20
- 238000005755 formation reaction Methods 0.000 description 13
- 239000000126 substance Substances 0.000 description 10
- 230000005764 inhibitory process Effects 0.000 description 9
- 238000011282 treatment Methods 0.000 description 8
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 8
- 230000006870 function Effects 0.000 description 7
- 239000000243 solution Substances 0.000 description 7
- 238000007726 management method Methods 0.000 description 5
- 239000000203 mixture Substances 0.000 description 5
- 238000001556 precipitation Methods 0.000 description 5
- 230000008569 process Effects 0.000 description 5
- 238000005516 engineering process Methods 0.000 description 4
- 238000002347 injection Methods 0.000 description 4
- 239000007924 injection Substances 0.000 description 4
- 238000001179 sorption measurement Methods 0.000 description 4
- 239000003795 chemical substances by application Substances 0.000 description 3
- 238000010276 construction Methods 0.000 description 3
- 238000010348 incorporation Methods 0.000 description 3
- 230000000638 stimulation Effects 0.000 description 3
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 2
- 150000001450 anions Chemical class 0.000 description 2
- 150000001768 cations Chemical class 0.000 description 2
- 238000005553 drilling Methods 0.000 description 2
- 238000001914 filtration Methods 0.000 description 2
- 239000008398 formation water Substances 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- 230000002401 inhibitory effect Effects 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- UEZVMMHDMIWARA-UHFFFAOYSA-M phosphonate Chemical compound [O-]P(=O)=O UEZVMMHDMIWARA-UHFFFAOYSA-M 0.000 description 2
- 238000002360 preparation method Methods 0.000 description 2
- 230000009467 reduction Effects 0.000 description 2
- 241000191291 Abies alba Species 0.000 description 1
- NIXOWILDQLNWCW-UHFFFAOYSA-N Acrylic acid Chemical class OC(=O)C=C NIXOWILDQLNWCW-UHFFFAOYSA-N 0.000 description 1
- KCXVZYZYPLLWCC-UHFFFAOYSA-N EDTA Chemical compound OC(=O)CN(CC(O)=O)CCN(CC(O)=O)CC(O)=O KCXVZYZYPLLWCC-UHFFFAOYSA-N 0.000 description 1
- QPCDCPDFJACHGM-UHFFFAOYSA-N N,N-bis{2-[bis(carboxymethyl)amino]ethyl}glycine Chemical compound OC(=O)CN(CC(O)=O)CCN(CC(=O)O)CCN(CC(O)=O)CC(O)=O QPCDCPDFJACHGM-UHFFFAOYSA-N 0.000 description 1
- 229910019142 PO4 Inorganic materials 0.000 description 1
- ABLZXFCXXLZCGV-UHFFFAOYSA-N Phosphorous acid Chemical class OP(O)=O ABLZXFCXXLZCGV-UHFFFAOYSA-N 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 238000013459 approach Methods 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 239000002738 chelating agent Substances 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 239000013078 crystal Substances 0.000 description 1
- 238000003795 desorption Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 238000009472 formulation Methods 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 230000036541 health Effects 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- -1 hydrogen ions Chemical class 0.000 description 1
- 239000008235 industrial water Substances 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 238000002955 isolation Methods 0.000 description 1
- 238000012423 maintenance Methods 0.000 description 1
- 230000008450 motivation Effects 0.000 description 1
- 235000021317 phosphate Nutrition 0.000 description 1
- 150000003013 phosphoric acid derivatives Chemical class 0.000 description 1
- 230000000717 retained effect Effects 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 238000000207 volumetry Methods 0.000 description 1
Images
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
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
- E21B37/06—Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting, e.g. eliminating, the deposition of paraffins or like substances
-
- 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
-
- 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
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/008—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by injection test; by analysing pressure variations in an injection or production test, e.g. for estimating the skin factor
Definitions
- Document EP 0040442 B1 describes a well treatment process comprising the composition of an aqueous solution containing scale inhibitor consisting essentially of water, at least one compound containing scale inhibitor anions, at least one compound containing multivalent cations, alkaline material sufficient to provide a solution pH that exceeds the pH at which a compound of these scales—inhibitory anions and multivalent cations will begin to precipitate at the reservoir temperature, and a sufficient quantity of at least one compound that reacts to produce hydrogen ions at a relatively slow rate to subsequently reduce the pH of the solution to one at which said precipitation will begin; and injecting the solution into the reservoir at a rate and volume arranged so that (a) substantially all of the solution enters the reservoir before any significant amount of said precipitation occurs and (b) a significant amount of said precipitation occurs while the solution is in a location close to the well inside the reservoir. It further mentions that, although a wide variety of materials inhibit crystal growth, the most commonly used compounds in well treatments are organic phosphates or phosphonates or
- the method proposed in the present invention may serve as a prior option for programming the squeeze operation in a reservoir, even in the well construction phase, in the completion step, in the injectivity test operations, having the technical advantage of taking advantage of the completion fluid that the well will absorb to perform a prior inhibition of the reservoir, thus using the porous spaces of the reservoir rock to reserve inhibited completion fluid, which will then be available within the reservoir to perform an inhibition scale, when producing oil from this reservoir.
- the completion fluid is prepared according to the operation program. This completion fluid is displaced until it reaches the perforations.
- the scale inhibitor will be added to the completion fluid that will be absorbed by the producing formation during the operation against losses, and in this way the inhibitor will be positioned inside the reservoir, and thus the reservoir will be inhibited. While the reservoir absorbs the fluid used in the fluid injection operation into the reservoir during the injectivity test operation, the completion fluid with the scale inhibitor will be positioned inside the reservoir, thus generating a chemical inhibition of scale formation within the reservoir.
- the selection of the inhibitor is carried out through the following tests: static compatibility test, flow test in capillary, flow test in porous medium. Table 1 shows the tests for inhibitor selection.
- the preferably-used scale inhibitors are the organophosphate compounds, and are incorporated directly into the completion fluid that will be used to carry out the injectivity test, with a concentration between 50 and 20000 ppm in the injectivity test fluid, four pumpings of 20 minutes, wherein there are two of 20 bpm ⁇ 20 minutes and two of 10 bpm ⁇ 20 minutes, which totals 600 bbl, and, in this volume, from 4.77 liters to 1900 liters will be the inhibitor, as follows:
- This system also presents the feasibility of carrying out the pre-inhibition by injecting the chemical product into the marine well, during the injectivity test operation to enable the pre-inhibition to be carried out.
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- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Analytical Chemistry (AREA)
- Physical Or Chemical Processes And Apparatus (AREA)
- Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
Abstract
Description
- This application claims, under 35 U.S.C. § 119(a), priority to and the benefit of Brazilian Patent Application No. 10 2022 021634 7, filed Oct. 25, 2022, which is incorporated by reference herein in its entirety.
- The present invention pertains to the field of reservoir management, more precisely in the field of controlling production losses through scale management, and refers to a method for applying scale inhibitor to completion fluids during injectivity test operations.
- The motivation for the invention originates from the need for chemical inhibition of the reservoir. To determine the injectivity index (II) of the well, an injectivity test is carried out, in which large volumes of fluid are injected until sufficient pressure data is obtained to generate a reliable curve from which the (II) will be estimated, among other reservoir parameters. The idea is to place a scale inhibitor in the formulation of the completion fluid that will be used during injectivity test operations in the completed wells, both in siliciclastic and carbonate formations, as is the case in the pre-salt.
- Thus, while the reservoir absorbs the fluid used in the fluid injection operation into the reservoir, during the injectivity test operation, the fluid with the scale inhibitor will be positioned inside the reservoir, thus generating a chemical inhibition of scale formation inside the reservoir.
- The approach generally previously used to solve the problem of the need to inhibit reservoirs in order to avoid the formation of scale, was simply the use of chemical inhibition through squeeze of inhibitor in reservoirs; however, this operation normally requires a stoppage to be carried out well production so that the inhibitor squeeze can be injected into the producing formation; next, an adsorption time of the inhibitor by the reservoir rock is necessary. After the adsorption time has elapsed, when the source rock adsorbs part of the scale inhibitor, the excess thereof is produced when the well is opened for production. This adsorption time is controlled to prevent damage to the reservoir from occurring. During the oil production, the inhibitor fluid that was adsorbed by the reservoir rock will begin a chemical desorption process, that is, it will be gradually released, thus inhibiting scale formation together with the water produced in the BSW of the oil produced.
- The solution achieved by the invention will be the use of the completion fluid used in injectivity test operations, to inhibit scaling in the reservoir by filling the porous spaces of the reservoir rock with the inhibited completion fluid. When the well is put into production, this inhibited fluid positioned inside the reservoir will be produced together with the oil and will inhibit the formation of scale inside the reservoir and on production equipment.
- The completion fluid is the fluid that is used in the construction phase of an oil well called completion, which corresponds to the preparation of the well to be equipped with completion equipment, such as the production string, production packers, flow valves that connect the well annulus to the interior of the oil well production string, chemical injection mandrels for dosing products, PDG sensors to measure temperature and pressure, the safety valve that is the down hole safety valve (DHSV) and wet Christmas tree.
- The fluid is defined as a function of the hydrostatic pressure that it must exert on the producing formation, its main function is to keep the well damped, that is, to not allow the production of oil from the reservoir into the oil well, during the completion operations, that is, the running in and installation of production equipment in the well. The density of the fluid in Lb/gal is multiplied by the vertical depth, (TVD, true vertical depth) of the well in meters, times 0.17 (unit and gravity conversion).
- Document EP 0040442 B1 describes a well treatment process comprising the composition of an aqueous solution containing scale inhibitor consisting essentially of water, at least one compound containing scale inhibitor anions, at least one compound containing multivalent cations, alkaline material sufficient to provide a solution pH that exceeds the pH at which a compound of these scales—inhibitory anions and multivalent cations will begin to precipitate at the reservoir temperature, and a sufficient quantity of at least one compound that reacts to produce hydrogen ions at a relatively slow rate to subsequently reduce the pH of the solution to one at which said precipitation will begin; and injecting the solution into the reservoir at a rate and volume arranged so that (a) substantially all of the solution enters the reservoir before any significant amount of said precipitation occurs and (b) a significant amount of said precipitation occurs while the solution is in a location close to the well inside the reservoir. It further mentions that, although a wide variety of materials inhibit crystal growth, the most commonly used compounds in well treatments are organic phosphates or phosphonates or acrylic acid adducts or similar.
- Document PI 0108245-0 A refers to a method of treating a reservoir zone of a hydrocarbon producing well during the completion phase to inhibit problems associated with water production, the method comprising: deploying, in the region near the well of a reservoir zone during the completion phase, a hydrocarbon-compatible treatment agent in a hydrocarbon phase; allowing the active component of the treatment agent to irreversibly enter the connate water in the well region; and allowing the active component to be retained by the source rock in the well region, whereby the active component of the treatment agent actively inhibits the respective problem if and when water is ultimately produced from the reservoir zone.
- Document U.S. Pat. No. 4,860,829 A relates to a treatment process for inhibiting scale by fluid that is produced from a non-carbonate underground reservoir through a wellbore, which comprises injecting into the wellbore and the reservoir a mixture of a phosphonate scale inhibitor compound and a calcium chelate, wherein the calcium chelate has a lower stability constant (Ke) than the phosphonate inhibitor.
- The method proposed in the present invention, in a different way to the state of the art, may serve as a prior option for programming the squeeze operation in a reservoir, even in the well construction phase, in the completion step, in the injectivity test operations, having the technical advantage of taking advantage of the completion fluid that the well will absorb to perform a prior inhibition of the reservoir, thus using the porous spaces of the reservoir rock to reserve inhibited completion fluid, which will then be available within the reservoir to perform an inhibition scale, when producing oil from this reservoir.
- Additionally, the technology proposed in the present invention can be applied entirely through the Wells field, being addressed to the Reservoirs field for scaling management and, in the Lift and Flow field, it will contribute to ensuring the flow of production from the wells. It can be applied as part of the technology used in the construction of wells in the completion phase in injectivity test operations as part of the technology used in the completion fluids, wherein only the planning of the addition of the inhibitor chemical product in the manufacture of the completion fluid is required.
- The present invention aims at proposing a method for applying scale inhibitor to completion fluids during injectivity test operations comprising the following steps: (a) definition of the function and type of the completion fluid (generally water-based fluids, which can be desulfated, industrial water or seawater); (b) selection of inhibitor compatible with the completion fluid and rock formation; (c) sizing of the volume of scale inhibitor to be consumed; (d) incorporation of the inhibitor into the fluid in a tank or mixer present in the marine rig.
-
FIG. 1 presents the circulation system of a completion rig, in which the scale inhibitor is applied. - The present invention relates to a method for applying the scale inhibitor to completion fluids during injectivity test operations, comprising the following steps:
-
- (a) definition of the function and type of the completion fluid (generally seawater-based fluids);
- (b) selection of inhibitor compatible with the completion fluid and rock formation;
- (c) sizing of the volume of scale inhibitor to be consumed;
- (d) incorporation of the inhibitor into the fluid in a tank or mixer present in the marine rig.
- In the injectivity test operations, the completion fluid is prepared according to the operation program. This completion fluid is displaced until it reaches the perforations. The scale inhibitor will be added to the completion fluid that will be absorbed by the producing formation during the operation against losses, and in this way the inhibitor will be positioned inside the reservoir, and thus the reservoir will be inhibited. While the reservoir absorbs the fluid used in the fluid injection operation into the reservoir during the injectivity test operation, the completion fluid with the scale inhibitor will be positioned inside the reservoir, thus generating a chemical inhibition of scale formation within the reservoir.
- The selection of the inhibitor is carried out through the following tests: static compatibility test, flow test in capillary, flow test in porous medium. Table 1 shows the tests for inhibitor selection.
-
TABLE 1 Tests for inhibitor selection. Type of Test Obtained Result Note Static Scale inhibitor and No precipitation or compatibility formation water are turbidity of water test compatible occurred when compared to blank test (with formation water only) Flow test in No inhibitor Determination of the capillary precipitation occurs minimum inhibitor under flow concentration that conditions as a must be used to function of time guarantee the effectiveness of the process Flow test in Test with the Obtaining the porous reservoir rock plug absorption isotherm medium to obtain the is essential to adsorption isotherm obtain the duration that will be used to of the treatment size the volumetries that will be applied in the treatment - Thus, the preferably-used scale inhibitors are the organophosphate compounds, and are incorporated directly into the completion fluid that will be used to carry out the injectivity test, with a concentration between 50 and 20000 ppm in the injectivity test fluid, four pumpings of 20 minutes, wherein there are two of 20 bpm×20 minutes and two of 10 bpm×20 minutes, which totals 600 bbl, and, in this volume, from 4.77 liters to 1900 liters will be the inhibitor, as follows:
-
- Pumping 20 m3/d of seawater between 50 and 20000 ppm of scale inhibitor for 20 min, followed by monitoring the pressures and temperatures during this pumping;
- Pumping 20 m3/d of seawater between 50 and 20000 ppm of scale inhibitor for 20 min, followed by monitoring the pressures and temperatures during this pumping;
- Pumping 10 m3/d of seawater between 50 and 20000 ppm of scale inhibitor for 20 min, followed by monitoring the pressures and temperatures during this pumping;
- Pumping 10 m3/d of seawater between 50 and 20000 ppm of scale inhibitor for 20 min, followed by monitoring the pressures and temperatures during this pumping.
- This will be obtained by adding the inhibitor to the completion fluid, which will be prepared in a tank on the completion platform.
- The incorporation of the completion fluid is carried out in the circulation system of a completion rig, including the completion rig pumping system, which are the equipment used during operations with completion fluid, and which are used, such as the rig tanks for fluid preparation. Said system, represented by
FIG. 1 , presents the following equipment: -
- Fluid supply tank (1): place where the fluid is prepared and stored until it is used. It has a stirrer for homogenizing the fluid;
- Rig pump (2): used to pump fluids from the tank to the oil well;
- Standpipe manifold (3): used to align fluids to be pumped between different equipment, from tanks and/or filtration units and also to the oil well;
- Check valve (4): used to prevent the return of fluid, through the alignment that goes to the well, towards equipment such as pump and/or filtration unit;
- Relief line (5): used to divert fluid flow with the functions of unloading or decompressing unwanted pressure in the pumping lines;
- Injection head (6): used at the upper end of the string, for connection with the pumping lines, which has flexibility to allow the movement of the string inside the well, in movements resulting from swell and river.
- Rotary table (7): it is positioned on the floor of the rig, whose function is to allow access to the drilling and/or completion string to carry out operations inside the well, such as, for example, connecting the pipes both of drilling and completion string.
- Well Scheme (8): represents a schematic drawing of the well components, such as casings, perforations to connect the reservoir to the interior of the well, isolation packers, production string and flow valves positioned at intervals.
- This system also presents the feasibility of carrying out the pre-inhibition by injecting the chemical product into the marine well, during the injectivity test operation to enable the pre-inhibition to be carried out.
- Reliability
- It improves the guarantee of production flow by preventing the early formation of scale, which increases well productivity time without the need for intervention, thus avoiding production losses associated with scales.
- Social
- It collaborates in maintaining the payment of oil royalties in order to promote the maintenance of production and avoid production losses.
- Economic/Productivity
- It prevents losses in oil production in the case of the generation of incompatible mixtures with a high potential for scale formation arising from the mixture of the fluid injected into the reservoir with water from the aquifer, thus avoiding the financial loss associated with loss of production. Carrying out a removal and inhibition operation to eliminate the damage process caused by scale necessarily generates a production stoppage of the oil well for at least 5 days; considering the average production of a well in Búzios of 8000 m3/d and considering the barrel at US$96, it would bring savings of R$24,000,000.00 per day.
- It reduces the number of interventions with stimulation boats, generating savings of R$9,000,000.00 per operation carried out for the Búzios field.
- It avoids rig interventions during the field development phase. Depending on the type of scale that may be formed, it could be necessary to use a completion rig to remove the scale using equipment with coiled tubing and drill associated with chemical chelators such as DTPA and/or EDTA. Considering that the average time for this type of operation lasts around 15 days, and that the average rig daily is around US$500,000.00 per day, there would be a saving of R$ 37,500,000.00.
- Health/Safety
- It reduces the need for operations with stimulation boats to pump scale-removing solutions from the well production string and to carry out inhibitor squeeze operations. In this way, there is a reduction in the risk associated with disconnections in the pumping system of the stimulation boats and the possibility of chemical leaks into the sea.
- Other Advantages
- It improves scaling management and thus contributes to increasing the efficiency of the reservoir management in the fields in which this technology is applied.
- Environmental
- It reduces CO2 emissions due to the reduction in the need of using a WSSV-type vessel to carry out scale removal and inhibitor squeeze operations.
Claims (5)
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
BR102022021634-7A BR102022021634A2 (en) | 2022-10-25 | METHOD FOR APPLICATION OF SCALE INHIBITOR IN COMPLETION FLUIDS DURING INJECTION TESTING OPERATIONS | |
BR1020220216347 | 2022-10-25 |
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US20240133268A1 US20240133268A1 (en) | 2024-04-25 |
US20240229605A9 true US20240229605A9 (en) | 2024-07-11 |
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US18/493,160 Pending US20240229605A9 (en) | 2022-10-25 | 2023-10-24 | Method for applying the scale inhibitor to completion fluids during injectivity test operations |
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US11584878B1 (en) * | 2021-12-16 | 2023-02-21 | Halliburton Energy Services, Inc. | Acid precursors for enhanced inhibitor placement in scale squeeze treatments |
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US5224543A (en) * | 1991-08-30 | 1993-07-06 | Union Oil Company Of California | Use of scale inhibitors in hydraulic fracture fluids to prevent scale build-up |
US20100047156A1 (en) * | 2006-08-15 | 2010-02-25 | Mekorot Israel National Water Company, Ltd. | Multiple stage reverse osmosis method for removing boron from a salinated fluid |
US7886822B2 (en) * | 2007-07-27 | 2011-02-15 | Schlumberger Technology Corporation | System, method, and apparatus for acid fracturing with scale inhibitor protection |
CA2901517C (en) * | 2013-03-08 | 2017-08-29 | Baker Hughes Incorporated | Method of enhancing the complexity of a fracture network within a subterranean formation |
-
2023
- 2023-10-24 US US18/493,160 patent/US20240229605A9/en active Pending
- 2023-10-25 CN CN202311394659.5A patent/CN117927189A/en active Pending
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US11584878B1 (en) * | 2021-12-16 | 2023-02-21 | Halliburton Energy Services, Inc. | Acid precursors for enhanced inhibitor placement in scale squeeze treatments |
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