Unconventional Reservoir Enhanced Oil & Gas Recovery from perspective of ChemistryView this Special Issue
New Online Shunt Acidification for Water Injection Increasing Technology and Its Application in Huanjiang Oilfield
The poor physical property and strong heterogeneity of Triassic Yanchang formation in Huanjiang oilfield of Ordos Basin are the main reasons for uneven water absorption, partial injection wells underinjection at high pressure, and decline of production. Previously, large numbers of conventional acidifications were used for plugging removal in the reservoir, but the effect was not so good and effective period was short. Aiming at the geological characteristics of Huanjiang oilfield, an online shunt acidification and augmented injection technology which does not stop water injection, pull original production strings out, and continuously inject acid and diverting agent has been proposed. A chelating acid COA-1S with low corrosion rate (0.3675 g/(m2·h)), good retardation capacity (hydrolysis constant = 1.2 × 10−6), and effective chelating ability (precipitation inhibition rate >95%) has been developed, as well as a diverting agent COA-1P with good dispersion in acid solution, diversion effect, and particle size (10–100 μm), which behaves well in COA-1S acid. It has been proved that the online acid system has a good diversion acidizing ability and plugging removal performance in a deep area in the laboratory core physical simulation test. The field test results show that the online shunt acidizing and augmented injection technology could reduce the injection pressure significantly (4.2 MPa) and increase water injection by 10 m3/d for the measured well (H5) and improve the water injection profile prominently. The online shunting acidification and augmented injection technology have the following advantages: simple procedures, fewer equipment needed, high efficiency of depressurization, and increasing water injection, which could effectively improve the profile of water wells, and there is a bright future of the technology.
The main development layer of Huanjiang oilfield is the Triassic Yanchang formation, the average porosity of the reservoir is 10.9%, and the average permeability is 0.43 × 10−3 μm2, so Huanjiang oilfield belongs to the ultra-low-permeability sandstone reservoir. Due to poor physical properties of the reservoir and injected water not up to standard, as well as other reasons, many problems such as uneven water absorption, increasing water injection pressure, and more and more injecting wells underinjection have arised. In recent years, aiming at the problem of underinjection of Huanjiang oilfield, a series of measures have been carried out to reduce water injection pressure and increase water injection and have achieved great efforts; however, the effective period of these measures is short (average 79 days) and effective rate is low (average 73%). The main reasons are as follows: (1) because of the repeated acidification of wells, the damaging radius is getting bigger; (2) after acidification, the acid solution produced secondary damage and caused secondary blockage to the reservoir, and (3) due to strong heterogeneity of the reservoir, acid absorption of different layers varies and low-permeability layers absorb fewer acid, resulting in poor acidification effect .
Based on the geological characteristics of Huanjiang oilfield, an online shunt acidification and augmented injection technology with not stopping water injection, not pulling out the original production strings, and continuous injection of acid have been proposed. The field test results showed that the technology behaves well, which could greatly reduce the water injection, improve the water injection volume, and effectively improve the profile of the wells. It has a good application prospect, and there is a bright future of the technology [2, 3].
2. Analysis of the Theory and Adaptability of Online Diversion Acidification
2.1. Shunt Acidizing Theory
Generally, acid flows through the small layers linearly should obey Darcy law. In order to make the acid move into the per small layer (or small section) and reach the goal of plugging removal in each layer (section) proportionately, it must obey the rule that the acid injection rate on per unit area of small layers (or small section) is the same , which means it should meet the following relation:
In the relation, K- permeability, 10−3 μm2; ΔP- pressure difference, MPa; μ- injection viscosity, mPa·s; L- distance of pressure differential, m3; and N- total amount of layers.
Due to the affect of damage degree, reservoir pressure, fluid compressibility, fluid viscosity, and natural seam hole development of small layers (or small section) , when measures are not taken, the relation is not met; therefore, temporary plugging or shunt technology should be considered.
The online shunt acidification is an injection process which does not need to pull the original pipes out during acidification; meanwhile, acid and diverting agent are injected together with water. In the early stage, the acid prefers to enter the high-permeability layer, as the effect of the diverting agent, permeability of high permeability layer would decrease with increase entering of diverting agent, therefore, the subsequent acid would rather enter other layers with low permeability, and finally, the goal of acid entering into all layers proportionally is achieved .
2.2. Performance Evaluation of Chelating Acid
Chelate acid (COA-1S) is a kind of multivariant organic acid, with 24 O2−, 12 OH− and 6 PO3−, and N and O heteroatoms which contain unshared electron pairs with the greater electronegativity, and when the groups encounter Ca2+, Ba2+, Sr2+, Fe3+, and other high-valence metal cations, stable complexes are easily generated, which are very stable in the wide range of pH value . Table 1 shows the chelating performance of the acid solution. It can be seen that compared with mud acid and multihydrogen acid, chelate acid (COA-1S) is superior in inhibiting precipitation, with the pH value of the solution increased from 3 to 7, the precipitation inhibition rate of COA-1S to Ba2+ increases rapidly, indicating the increase of pH value caused by acid consumption does not reduce chelating ability, and the resulting complex are stable enough to prevent the secondary precipitate.
The hydrolysis equilibrium constant of chelate acid (COA-1S) is only about 1.2 × 10−6; therefore, the concentration of chelating acid is very low when hydrolysis equilibrium is reached, and the hydrolysis reaction process is slow. In the process of acidizing and plugging removal, in order to maintain the equilibrium of hydrolysis, the ionized H+ generally reacts with sandstone minerals, thus slowing down the reaction rate of acid and rock and achieving the goal of plugging removal in the deep area. Comparing with conventional mud acid, the superior performance in retardation of COA-1S provides a guarantee for improving the acidification effect in the deep area.
Referring to the SY/T 5405–1996 “Performance test method and evaluation index of corrosion inhibitor for acidification,” the corrosion rate of COA-1S (50%) for N80 steel sheet and tube column coated is determined under 60oC, and the corrosion rates are 0.2895 g/(m2·h) and 0.3675 g/(m2·h), respectively, and the results are only 10% of the industry standard level (3.0 g/(m2·h), which indicates that COA-1S has less corrosion to inner tubes, and the pictures of steel sheets before and after corrosion tests (shown in Figure 1) also support the standpoint.
2.3. Performance Evaluation of the Diverting Agent
The diverting agent COA-1P is a kind of salt substance, which is a colorless transparent liquid with a density of 1.07 g/cm3. Figure 2 shows solubility evaluation results of the diverting agent. It can be seen that the solution is clear and transparent when diverting agent COA-1P mixes with tap water, and when mixing diverting agent COA-1P with the chelate acid COA-1S, uniform and dispersed white small particles are produced. With the increase in the amount of tap water, the pH value of the solution increases gradually, and the white particles gradually dissolve and are completely dissolved when the pH value is 7. During onsite operation, firstly, the chelate acid COA-1S should be injected into the formation to remove pollution in the zone; secondly, the diverting agent is added to produce chemical particles to form temporary plugging; thirdly, chelate acid COA-1S is injected again to be forced to flow to the low-permeability zone, aiming at improving the longitudinal water absorption section of water injection wells; finally, the normal water injection is recovered to relieve the blockage of the diverting agent to the high-permeability zone.
In order to fully understand the distribution of the particle size of the diverting agent COA-1P in the acid solution, the particle size distribution of COA-1S and COA-1P mixed solution with different concentration is detected by using a laser particle size analyzer. The results are shown in Table 2. It can be seen from Table 2 that the resulting white particle size is mainly from 10 to 100 μm, and the pore throat of the target reservoir is mainly from 0.22 to 33.82 μm. Therefore, the size of the particle could be changed by adjusting the concentration of the acid liquid and the diverting agent, so as to achieve the purpose of blocking the high-permeability layer temporarily and meet the shunting requirements [8, 9].
2.4. Compatibility Evaluation
The compatibility tests for the chelate acid COA-1S and diverting agent COA-1P with injected water and formation water are carried out under the conditions of 20 and 60°C, respectively. The results show that the compatibility of the two liquids with injected water and the formation water is good at different temperatures.
3. Simulation Experiment Research of Online Shunt Acidification Experiment
In order to further verify the feasibility of the technology, parallel core flow tests are carried out using two cores with different permeabilities selected from the corresponding reservoirs in Huanjiang oilfield [10, 11], and the effects of shunt and acidification are analyzed. The experiment temperature is 60°C, and the experiment apparatus is the multifunctional shunt acidification experiment instrument which is self-developed. The results are shown in Figure 3 and Table 3.
Figure 3 is the pressure variation curve of the core of the H2 well after injecting acid and diverting agent. It can be seen that the pressure of core 1 changed little and the pressure of core 2 dropped after injecting 50% COA-1S acid, indicating that acid is mainly injected into core 2. After the injection of 6% COA-1P, the pressure of the two cores fluctuate greatly, and the pressure increases with the diverting agent and acid injecting sequentially, which indicate that the COA-1P played a temporary plugging role. The pressure drops sharply with injection of stratum water after the acid liquid, which shows that COA-1P is dissolved by water and it does not plug the formation during the normal water injection.
Table 3 shows the results of permeability before and after the shunt acidification tests. It can be seen that the permeability of core 1 and 2 increase by 10.5 and 3.1 times, respectively, indicating that the diverting agent has effectively plugged core 2 and both the two cores have been completely acidified, and the effect of shunt acidification is good.
4. Field Application Example
4.1. Basic Situation and Analysis of Site Operation
On October 15, 2017, the onsite operation of online shunt acidification in well H5 of Huanjiang oilfield was carried out (shown in Figure 4), the dosage of shunt agent COA-1P was 2 m3, and the dosage of chelate acid was 17.4 m3. The operation procedures are as follows: (1) Pressure test and water squeeze. (2) The first stage of acid COA-1S was injected into the formation to remove reservoir choke and reduce the water injection pressure. The operation flow rate was 1.0 m3/h–3.0 m3/h, and the ratio of acid COA-1S to injected water was 1 : 1.5. The cumulative injection volume was 12 m3, of which 4.8 m3 acid liquid was squeezed from the well test valve to the reservoir, and the rest was injected from the normal process to the reservoir. (3) The second stage mixed solution of acid COA-1S and shunt COA-1P was injected into the formation, the flow rate of diverting agent was 1.0 m3/h, and the injection volume of diverting agent was 2 m3; while the flow rate of acid solution was 1.2 m3/h, and the cumulative injection volume of acid solution was 2.4 m3. (4) The third stage acid solution was injected into the formation. The operation flow rate was 1.2–3.0 m3/h, and the ratio of acid COA-1S to injected water was 1 : 1, 10.2 m3 of acid liquid was squeezed from the oil pipe to the reservoir, and the other 10.2 m3 of water was injected from the distribution room to the casing pipe. (5) The water injection process was recovered. The water injection pressure was 16.5 MPa, and the instantaneous flow rate was 1.0 m3/h.
The operation curve is shown in Figure 5. It can be seen that, (1) when the sleeve valve was open, the acid liquid was squeezed into the formation and the pressure rose, indicating that it was difficult for the formation to absorb the water. (2) In the process of acid injection under high pressure, the operation pressure increased from 15.3 MPa to 17.3 MPa after the acid entered the well bottom, which indicated that the diverting agent played an effective role in plugging the high permeability layer. (3) At the end of acidification, the pressure of was 16.5 MPa after the injection pump was stopped. After recovering the water injection process, the water injection pressure decreased from 17.3 to 16.5 MPa. At present, the injection pressure was 14.9 MPa, which dropped 4.2 MPa comparing with not operated before, indicating that the effect of acid liquid for plugging removal was obvious. (4) From 14 : 29 to 2 : 57, the whole construction cycle which was reduced at least 1 to 7 times was less than 13 hours, compared with the conventional profile adjustment technology for more than 7 days. In the process of acidification operation, there were no need of leakage of the water in the tube, pulling the original pipes out, changing acid, and flowback of the residual liquor. Online shunt acidizing technology greatly simplified the conventional acidification process and shortened the operation period. Moreover, in contrast to the soil pollution caused by the conventional profile adjustment technology, which needed to drain water and regurgitate reacted acid to the ground, it reduced the risk of safety and environmental pollution. Last, during the conventional profile adjustment construction, the well must be off when tripping operation and changing acid, but water and acid mixed liquid could be injected at the same time, and the original injection process would not be stopped, which did not affect the normal water injection of water injection wells in the process of online shunt acidizing.
4.2. Profile Adjustment
Figure 6 shows the variation of the water absorption profile before and after the online shunt acidification of the H5 well. It can be seen that the upside of operated wells (2628–2638 m) absorbed water weakly and the lower section of wells (2638–2643 m) showed obvious characteristics of water absorption. The maximum water absorption intensity was 3.47 m3/d·m, and the degree of water absorption was only 28.5%. After the online shunt acidification, the upper and lower section of wells absorbed balanced water amount, the average water absorption intensity was 1.42 m3/d·m, and the degree of water absorption was 50.9%. The results demonstrated that the online shunt acidification could achieve well-proportioned acid distribution and improve the water absorption profile of the operated well effectively.
4.3. Effect of Depressurization and Injection Augment
Figure 7 shows the water injection curve before and after online shunt acidification of the H5 well. Before acidification, the oil pressure was 19.1 MPa, the allocation injection amount of water was 25 m3/d, and the actual water injection amount was 15 m3/d. After acidification, the oil pressure was 14.9 MPa, the allocation injection amount of water was 25 m3/d, and the actual daily injection amount was 25 m3/d. The water absorption index increased two times as before, and the effect of decrease of pressure and increase water injection was obvious.
5. Conclusions(1)Compared with conventional mud acid and multihydrogen acid, chelate acid COA-1S is superior in corrosion rate, retardation capacity, and chelating ability, which could slow down acidification rate, increase the time of operation, prolong acidification distance, reduce secondary precipitation of barium and strontium, and improve the effect of acidification.(2)The water-soluble diversion agent COA-1P could produce chemical particles when in contact with acid liquid and can make the proportional distribution of acid in the objective layer and improve the utilization of acid liquid, as well as the longitudinal water absorption profile of wells underinjection. Moreover, the diversion agent COA-1P could completely dissolve in the formation water and the injected water, which did not cause secondary plugging to the formation.(3)The online shunt acidification augmented injection technology was successfully applied in the H5 well of Huanjiang oilfield. It is proved that the technology had good applicability for the similar reservoirs and had important significance for improving the effect of water injection in similar oilfields.(4)Based on the different blockage reasons of each block of the ultra-low-permeability reservoir in Huanjiang Oilfield, the continuous injection online diversion acidification technology will act as the main part, with different other injection parts, such as inhibiting scale part and preventing clay swelling part and nanoaugmented injection, forming a set of online injection process systems, to solve the problems of high-pressure water wells underinjection in ultra-low-permeability reservoirs effectively.
The data used to support the findings of this study are included within the article.
Conflicts of Interest
The authors declare no conflicts of interest regarding the publication of this paper.
This work was financially supported by the National Natural Science Foundation of China (51402220), Key Project of Hubei Education Department (D20191503), and Wuhan Institute of Technology Science Foundation (K201801).
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