In-situ heat generation and thermal drive method for deep heavy oil

Abstract

The present application relates to heavy oil development method technical field, it is a kind of deep layer special heavy oil in-situ heat heat drive pressure development method, including setting well pattern structure, under the well pattern structure, pipe string is implemented deep layer special heavy oil reservoir development, the pipe string includes concentric double-layer tubing, anchor and packer, concentric double-layer tubing includes inner tubing and outer tubing located in the outer side of inner tubing, and the well pattern structure is used to implement drive pressure and release oil with good pipe string.The present application uses existing well pattern, establishes the liquid flow communication channel of injection-production well by radiating type hydraulic jetting communication method;Utilize layered injection pipe string, after upper part of oil layer is ignited, inject air, lower oil layer section plug injection water, realize the drive pressure and release oil of lower oil layer in deep layer special heavy oil reservoir fire flooding process, reach more than 60% recovery of fire flooding.

Description

Technical Field

[0001] This invention relates to the technical field of heavy oil development methods, specifically a method for the in-situ thermal drive and pressure development of deep extra-heavy oil. Background Technology

[0002] Currently, the remaining reserves of conventional crude oil resources are rapidly declining. To ensure energy security, it is essential to promote the development of heavy oil reservoirs and remaining oil reservoirs. Heavy oil has high viscosity and poor fluidity; multiple rounds of development have led to a decrease in the oil saturation of near-wellbore reservoirs, resulting in reduced economic benefits. In response to these issues, China National Petroleum Corporation's Liaohe Oilfield and Xinjiang Oilfield have repeatedly used fire-assisted ignition technology in heavy oil reservoirs, accumulating considerable experience in its implementation. Its economic and environmental advantages are gradually becoming apparent.

[0003] Conventional fire-flooding development methods require heavy oil viscosity of less than 5000 mPa·s and reservoir depth of less than 2000 m. Excessive viscosity and depth can lead to excessive displacement pressure on the fire line, hindering efficient displacement. In extra-heavy oil reservoirs, where crude oil viscosity exceeds 10000 mPa·s, especially in deep extra-heavy oil reservoirs, the significant heat loss along the steam path renders conventional steam recovery methods unusable. Furthermore, the large difference in water-oil mobility ratio results in low recovery rates with water-flooding, and ineffective water circulation increases the economic cost of crude oil extraction. Gravity-fired flooding using extra-heavy oil suffers from concentrated oil drainage in horizontal wells, limiting the three-dimensional expansion of the fire line and hindering large-scale field deployment. Therefore, it is necessary to develop a fire-flooding development method specifically for deep extra-heavy oil reservoirs, achieving in-situ heat generation, efficient displacement, and balanced fire line expansion, thus enabling the efficient development of deep extra-heavy oil reservoirs. Summary of the Invention

[0004] This invention provides a method for the in-situ thermal displacement and development of deep extra-heavy oil reservoirs, which overcomes the shortcomings of the prior art and can effectively improve the recovery rate of deep extra-heavy oil reservoirs.

[0005] The in-situ heat generation and thermal displacement development method for deep extra-heavy oil provided by this invention is applicable to deep extra-heavy oil reservoirs with a crude oil viscosity greater than 10,000 mPa·s and a burial depth exceeding 2,500 m. These reservoir conditions can lead to intense combustion, which is a prerequisite for water injection displacement, and by injecting water, the excessively intense combustion in the reservoir is prevented.

[0006] The technical solution of this invention is achieved through the following measures: a method for developing deep extra-heavy oil through in-situ heat generation and thermal pressure, comprising setting up a well network structure, wherein the well network structure is: setting up injection wells and production wells, establishing a fluid flow connection channel between injection and production wells through a radial hydraulic jet connection method, with injection wells radiating to corner wells, the connection distance between injection wells and corner wells being one-quarter to one-third of the distance between injection and production wells, and production wells radiating laterally or longitudinally without connecting direct channels between injection and production wells, thereby improving the front-edge sweep efficiency of the fire line, and establishing a connection channel at the bottom of the well through a hydraulic jet method; Under the aforementioned well network structure, tubing is inserted to develop deep, extra-heavy oil reservoirs. The tubing string includes concentric double-layer tubing, an anchor, and a packer. The concentric double-layer tubing includes an inner tubing and an outer tubing located outside the inner tubing. The lower outlet of the inner tubing extends downward from the lower outlet of the outer tubing. The anchor and packer are connected from top to bottom to the outer tubing of the concentric double-layer tubing. A side vent is provided on the inner tubing below the outer tubing, and a sliding sleeve is provided at the side vent. The lower outlet of the outer tubing serves as the first outlet of the tubing string, and the lower outlet of the inner tubing serves as the second outlet of the tubing string. Specifically, it includes: Step 1: The tubing string is lowered into the set position in the injection well. Water is injected into the inner and outer tubing of the concentric double-layer tubing at the same time to establish fluid communication between the injection and production wells, which is manifested as an increase in the production volume and water content of the production well. Step 2: Inject diesel fuel into the annulus (the annulus between the concentric double-layer tubing and the casing) to reduce the viscosity of heavy oil in the near-wellbore zone and improve displacement efficiency. Step 3: Nitrogen gas is injected into both the inner and outer oil pipes of the concentric double-layer oil pipe simultaneously; Step 4: Inject hot air at a temperature of 200°C to 250°C into the inner tubing (center tubing). The hot air enters the oil layer from the side outlet of the inner tubing and ignites the oil layer. After ignition, move the sliding sleeve and close the side outlet. The air injection channel is changed to the oil-sleeve annulus. One month after ignition, start injecting water into the inner tubing. The purpose is to make full use of the heat of the formation and the flue gas from the fire drive to drive the oil layer fluid to the production well.

[0007] The following are further optimizations and / or improvements to the above-mentioned technical solution: Furthermore, in step 1 above, the insertion positions of the tubing string are as follows: the first outlet of the concentric double-layer tubing is 3 to 5 meters away from the top boundary of the oil layer, the second outlet of the concentric double-layer tubing is 5 to 10 meters below the bottom boundary of the oil layer, and the anchor and packer are located more than 30 meters above the top boundary of the oil layer.

[0008] Furthermore, in step 2 above, the amount of diesel fuel injected is 20 to 22 tons per 10 meters of oil layer.

[0009] Furthermore, in step 3 above, the nitrogen injection rate is 800 to 850 standard cubic meters per meter of oil layer, and the injection time is 1 to 2 days.

[0010] Furthermore, in step 4 above, the injection intensity of hot air at 200°C to 250°C is 500 to 600 standard cubic meters per meter of oil layer, and the injection time is 7 to 15 days.

[0011] Furthermore, in step 4 above, the water injection rate is 20 to 23 cubic meters per day, the initial slug injection volume is 60 to 65 cubic meters, and a slug is injected every month, with the water volume increasing by 5 cubic meters each time.

[0012] Furthermore, in step 4 above, to ensure safe and efficient implementation, a safety control method was designed for the fire-flooding process, including: when a sudden increase in injection temperature and pressure occurs during ignition, with a pressure difference exceeding 10 MPa from the initial pressure and continuing to increase, cooling water (above zero degrees Celsius to room temperature) is injected into the annulus of the concentric double-layer tubing to displace near-well hot fluids to deeper reservoir depths; when the oxygen content in the production exhaust gas exceeds the standard and the reservoir combustion temperature is low (below the threshold temperature for heavy oil combustion, generally 360°C to 400°C), 20 to 50 cubic meters of linseed oil are injected into the annulus, followed by direct injection of room temperature air. This ensures the safety of the implementation process and the efficient advancement of the high-temperature combustion front in fire-flooding.

[0013] Flaxseed oil has a low ignition temperature, and it can spontaneously combust at around 100°C. Other oils have higher ignition temperatures and require the addition of combustion-aiding agents to lower their spontaneous combustion temperature.

[0014] The deep extra-heavy oil in-situ heat generation and thermal drive development method of this invention utilizes the existing well network and establishes a fluid flow connection channel between injection and production wells through a radial hydraulic jet connection method; using a stratified injection string, air is injected after ignition in the upper oil layer, and water is injected in the lower oil layer section by plug injection (conventional method of water injection in the upper layer and air injection in the lower layer to achieve gas-water injection and reduce over-coverage), to achieve the pressure discharge of the lower oil layer during the fire flooding process of deep extra-heavy oil reservoirs. Attached Figure Description

[0015] Appendix Figure 1 This is a diagram of the well network structure of the present invention.

[0016] Appendix Figure 2 This is a diagram of the tubular column of the present invention.

[0017] Appendix Figure 3 This is a flowchart of the present invention.

[0018] The codes in the attached diagram are as follows: 1 is the anchor, 2 is the packer, 3 is the inner tubing, 4 is the outer tubing, 5 is the sliding sleeve, 6 is the first outlet, 7 is the second outlet, and 8 is the perforation. Detailed Implementation

[0019] The present invention is not limited to the following embodiments, and specific implementation methods can be determined according to the technical solutions and actual conditions of the present invention.

[0020] In this invention, for ease of description, the description of the relative positions of the components is based on the appendix to the specification. Figure 2 The layout is described using a diagrammatic method, such as the positional relationships of front, back, top, bottom, left, and right, which are based on the instructions attached. Figure 2 The orientation of the layout is determined by the direction of the map.

[0021] In this invention, room temperature generally refers to a temperature between 15°C and 25°C, and is generally defined as 25°C.

[0022] This invention proposes a method for in-situ thermal flooding and depressurization development of deep extra-heavy oil reservoirs. First, a well network for in-situ thermal flooding and depressurization development is constructed. Utilizing the existing well network, injection wells and production wells are modified using a radial hydraulic jet connection method to establish fluid flow communication channels between the injection and production wells. Second, the injection tubing, injection method, and injection parameters for the injection wells are designed. Using a layered injection tubing, air is injected after ignition at the top, and water is injected in a slug-type manner at the bottom to achieve pressure relief and oil release from the lower oil layer during fire flooding of deep extra-heavy oil reservoirs. Then, safety measures are established during fire flooding, and the combustion effect at the fire front is controlled through water injection and combustion-supporting methods. Finally, this method for in-situ thermal flooding and depressurization development of deep extra-heavy oil reservoirs is formed.

[0023] This invention provides a method for in-situ thermal displacement and development of deep extra-heavy oil, including setting up a well network structure. The well network structure comprises injection wells and production wells, establishing fluid flow communication channels between the injection and production wells through a radial hydraulic jet connection method. Injection wells radiate to corner wells, with the connection distance between injection wells and corner wells being one-quarter to one-third of the distance between injection and production wells. Production wells and injection wells radiate laterally or longitudinally, without direct connection between injection and production wells, thereby improving the frontal sweep efficiency. Figure 1 As shown, the yellow dot is the central gas injection well, and the red dot is the oil production well (i.e., the production well). A connecting channel is established at the bottom of the well using a hydraulic jetting method. Under the aforementioned well network structure, tubing is inserted to develop deep, extra-heavy oil reservoirs. As attached Figure 2As shown, the tubing string includes concentric double-layer tubing, anchor 1, and packer 2. The concentric double-layer tubing includes an inner tubing 3 and an outer tubing 4 located outside the inner tubing 3. The lower end outlet of the inner tubing 3 extends downward from the lower end outlet of the outer tubing 4. Anchor 1 and packer 2 are connected from top to bottom to the outer side of the outer tubing 4 of the concentric double-layer tubing. A side vent is provided on the inner tubing 3 below the outer tubing 4. A sliding sleeve 5 is provided at the side vent. The lower end outlet of the outer tubing 4 serves as the first outlet 6 of the tubing string, and the lower end outlet of the inner tubing 3 serves as the second outlet 7 of the tubing string. As attached Figure 3 As shown, the specific steps include: Step 1: The tubing string is lowered into the set position in the injection well. Water is injected into the inner tubing 3 and outer tubing 4 of the concentric double-layer tubing at the same time to establish fluid communication between the injection and production wells, which is manifested as an increase in the production volume and water content of the production well. The tubing is positioned as follows: the first outlet 6 of the concentric double-layer tubing is 3 to 5 meters from the top boundary of the oil layer; the second outlet 7 of the concentric double-layer tubing is 5 to 10 meters below the bottom boundary of the oil layer; and the anchor 1 and packer 2 (a thermal packer 2 can be used) are located more than 30 meters above the top boundary of the oil layer.

[0024] The injection well perforation 8 is divided into two sections: the upper third and the lower third of the oil layer. The tubing string is positioned so that the lower third of the oil layer is used for liquid displacement, while the upper third is used for gas injection and venting. A heat-sensitive packer 2 and an anchoring device are connected to the outer tubing 4 more than 30 meters above the top boundary of the oil layer to effectively protect the casing of old wells. The casing and tubing in the oil layer section and the upper 50 meters of the oil layer are all fitted with or made of 13Cr steel casing, while the remaining tubing is made of 3Cr steel.

[0025] Step 2: Inject diesel fuel into the annulus (the annulus between the concentric double-layer tubing and the casing). The injection volume is 20 to 22 tons of diesel fuel per 10 meters of oil layer to reduce the viscosity of heavy oil in the near-wellbore zone and improve the displacement efficiency. Step 3: Nitrogen gas is injected into the inner oil pipe 3 and the outer oil pipe 4 of the concentric double-layer oil pipe at the same time. The injection rate is 800 to 850 standard cubic meters per meter of oil layer, and the injection time is 1 to 2 days. Step 4: Inject hot air at a temperature of 200℃ to 250℃ into the inner tubing 3 (center tubing). The injection intensity is 500 to 600 standard cubic meters per meter of oil layer. The injection time is 7 to 15 days. The hot air enters the oil layer from the side outlet of the inner tubing 3 and ignites the oil layer. After ignition, move the sliding sleeve 5 to close the side outlet and change the injection channel to annulus (injecting room temperature air). One month after ignition, start injecting water into the inner tubing 3 at a rate of 20 to 23 cubic meters per day. The initial slug injection volume is 60 to 65 cubic meters. Inject one slug every month, increasing the water volume by 5 cubic meters each time. The purpose is to make full use of the heat of the formation and the flue gas from the fire-driven operation to drive the oil layer fluid to the production well.

[0026] Example 1: A well in an extra-heavy oil reservoir in Xinjiang, with a burial depth of 2810m and crude oil viscosity of 13472 mPa·s. It adopted... Figure 1 The well network structure shown and Figure 2 The tubular column shown is used, and the method steps described are implemented: Step 1: The tubing string is lowered into the set position in the injection well. Water is injected into the inner tubing 3 and outer tubing 4 of the concentric double-layer tubing at the same time to establish fluid communication between the injection and production wells, which is manifested as an increase in the production volume and water content of the production well. Step 2: Inject diesel fuel into the annulus of the oil casing at a rate of 20 tons of diesel fuel per 10 meters of oil layer to reduce the viscosity of heavy oil in the near-wellbore zone and improve displacement efficiency. Step 3: Nitrogen gas is injected into the inner oil pipe 3 and the outer oil pipe 4 of the concentric double-layer oil pipe at the same time. The injection rate is 800 standard cubic meters of nitrogen per meter of oil layer, and the injection time is 2 days. Step 4: Inject hot air at a temperature of 200℃ into the inner oil pipe 3. The injection intensity is 550 standard cubic meters of hot air per meter of oil layer. The injection time is 11 days. The hot air enters the oil layer from the side outlet of the inner oil pipe 3 and ignites the oil layer. After ignition, move the sliding sleeve 5 to close the side outlet and change the injection channel to an annulus. One month after ignition, start injecting water into the inner oil pipe 3. The water injection rate is 20 cubic meters per day. The initial slug injection volume is 60 cubic meters. Inject one slug every month, and the water volume each time increases by 5 cubic meters compared to the previous time.

[0027] After the extra-heavy oil reservoir was developed using the thermal displacement method described in Example 1, the recovery rate reached 65%.

[0028] Example 2: A well in an extra-heavy oil reservoir in Xinjiang, with a burial depth of 2947m and crude oil viscosity of 14359 mPa·s. It adopted... Figure 1 The well network structure shown and Figure 2 The tubular column shown is used, and the method steps described are implemented: Step 1: The tubing string is lowered into the set position in the injection well. Water is injected into the inner tubing 3 and outer tubing 4 of the concentric double-layer tubing at the same time to establish fluid communication between the injection and production wells, which is manifested as an increase in the production volume and water content of the production well. Step 2: Inject diesel fuel into the annulus of the oil casing at a rate of 22 tons of diesel fuel per 10 meters of oil layer to reduce the viscosity of heavy oil in the near-wellbore zone and improve displacement efficiency. Step 3: Nitrogen gas is injected into the inner oil pipe 3 and the outer oil pipe 4 of the concentric double-layer oil pipe at the same time. The injection rate is 830 standard cubic meters of nitrogen per meter of oil layer, and the injection time is 2 days. Step 4: Inject hot air at a temperature of 220℃ into the inner oil pipe 3. The injection intensity is 570 standard cubic meters of hot air per meter of oil layer. The injection time is 9 days. The hot air enters the oil layer from the side outlet of the inner oil pipe 3 and ignites the oil layer. After ignition, move the sliding sleeve 5 to close the side outlet and change the injection channel to an annulus. One month after ignition, start injecting water into the inner oil pipe 3. The water injection rate is 22 cubic meters per day. The initial slug injection volume is 65 cubic meters. Inject one slug every month, and the water volume each time increases by 5 cubic meters compared to the previous injection.

[0029] After the extra-heavy oil reservoir was developed using the thermal displacement method described in Example 1, the recovery rate reached 62%.

[0030] Example 3: A well in an extra-heavy oil reservoir in Xinjiang, with a burial depth of 2615m and crude oil viscosity of 12588 mPa·s. It adopted... Figure 1 The well network structure shown and Figure 2 The tubular column shown is used, and the method steps described are implemented: Step 1: The tubing string is lowered into the set position in the injection well. Water is injected into the inner tubing 3 and outer tubing 4 of the concentric double-layer tubing at the same time to establish fluid communication between the injection and production wells, which is manifested as an increase in the production volume and water content of the production well. Step 2: Inject diesel fuel into the annulus of the oil casing at a rate of 22 tons of diesel fuel per 10 meters of oil layer to reduce the viscosity of heavy oil in the near-wellbore zone and improve displacement efficiency. Step 3: Nitrogen gas is injected into the inner oil pipe 3 and the outer oil pipe 4 of the concentric double-layer oil pipe at the same time. The injection rate is 850 standard cubic meters of nitrogen per meter of oil layer, and the injection time is 1 day. Step 4: Inject hot air at a temperature of 250°C into the inner oil pipe 3. The injection intensity is 550 standard cubic meters of hot air per meter of oil layer. The injection time is 14 days. The hot air enters the oil layer from the side outlet of the inner oil pipe 3 and ignites the oil layer. After ignition, move the sliding sleeve 5 to close the side outlet and change the injection channel to an annulus. One month after ignition, start injecting water into the inner oil pipe 3 at a rate of 20 cubic meters per day. The initial slug injection volume is 64 cubic meters. Inject one slug every month, and increase the water volume by 5 cubic meters each time.

[0031] After the extra-heavy oil reservoir was developed using the thermal displacement method described in Example 3, the recovery rate reached 67%.

[0032] In summary, this invention targets extra-heavy oil reservoirs with a burial depth exceeding 2500m and crude oil viscosity greater than 10000 mPa·s. It utilizes existing non-thermal recovery completion well networks (non-thermal recovery completions cannot achieve full-wellbore injection of hot fluids >250℃) to generate heat in situ, avoiding heat waste in the wellbore (conventional steam injection methods result in wellbore steam heat loss exceeding 50%). This invention achieves efficient displacement of reservoir fluids through well network setup, tubing structure, and injection fluid combination, achieving balanced expansion of the fire line (conventional fire flooding and gravity fire flooding cannot achieve efficient displacement of extra-heavy oil, easily leading to fire line breaches and fire flooding recovery rates of less than 20%). This invention ensures safe operation during fire flooding by designing fluid injection modes and combustion temperature control measures, achieving efficient development of deep extra-heavy oil reservoirs. The ignition temperature of heavy oil reservoirs has been reduced from 500℃ to 200℃, which reduces the difficulty of ignition; the temperature resistance requirements of completion tubing and cement have been reduced from 500℃ to 350℃, which reduces the difficulty of thermal recovery completion; and oil is driven by pressure to achieve a recovery rate of over 60% through fire-driven oil recovery.

[0033] The above technical features constitute the embodiments of the present invention, which have strong adaptability and implementation effect. Unnecessary technical features can be added or removed according to actual needs to meet the needs of different situations.

Claims

1. A method for in-situ thermal drive and pressure development of deep extra-heavy oil, characterized in that... This includes setting up a well network structure, inserting tubing strings under the well network structure to develop deep, extra-heavy oil reservoirs, wherein the tubing strings include concentric double-layer tubing, anchors, and packers, and the concentric double-layer tubing includes an inner tubing and an outer tubing located outside the inner tubing; specifically, it includes the following steps: Step 1: Lower the tubing string into the set position in the injection well, and simultaneously inject water into the inner and outer tubing of the concentric double-layer tubing to establish fluid communication between the injection and production wells. Step 2: Inject diesel fuel into the annulus of the oil casing to reduce the viscosity of heavy oil in the near-wellbore zone and improve displacement efficiency; Step 3: Nitrogen gas is injected into both the inner and outer oil pipes of the concentric double-layer oil pipe simultaneously; Step 4: Inject hot air into the inner tubing. The hot air enters the oil layer from the side outlet of the inner tubing and ignites the oil layer. After ignition, close the side outlet and change the air injection channel to the annulus. After ignition for a period of time, start injecting water into the inner tubing to make full use of the heat of the formation and the flue gas from the fire-driven process to drive the oil layer fluid to the production well.

2. The method for developing deep extra-heavy oil through in-situ heat generation and thermal drive as described in claim 1, characterized in that... The well network structure is as follows: injection wells and production wells are set up, and a fluid flow connection channel between the injection and production wells is established through a radial hydraulic jet connection method. The injection wells radiate to the corner wells, and the connection distance between the injection wells and the corner wells is one-quarter to one-third of the distance between the injection and production wells. The production wells and injection wells are connected laterally or longitudinally, without direct connection between the injection and production wells.

3. The method for developing deep extra-heavy oil reservoirs through in-situ heat generation and thermal drive pressure according to claim 1 or 2, characterized in that... In the tubing string, the lower end outlet of the inner tubing extends downward from the lower end outlet of the outer tubing. The anchor and packer are connected from top to bottom to the outside of the outer tubing of the concentric double-layer tubing. A side vent is provided on the inner tubing below the outer tubing, and a sliding sleeve is provided at the side vent. The lower end outlet of the outer tubing serves as the first outlet of the tubing string, and the lower end outlet of the inner tubing serves as the second outlet of the tubing string.

4. The method for developing deep extra-heavy oil reservoirs through in-situ heat generation and thermal drive pressure according to claim 1 or 2, characterized in that... In step 1, the tubing is lowered at the following positions: the first outlet of the concentric double-layer tubing is 3 to 5 meters from the top boundary of the oil layer, the second outlet of the concentric double-layer tubing is 5 to 10 meters below the bottom boundary of the oil layer, and the anchor and packer are located more than 30 meters above the top boundary of the oil layer.

5. The method for developing deep extra-heavy oil reservoirs through in-situ heat generation and thermal drive pressure according to claim 1 or 2, characterized in that... In step 2, the amount of diesel fuel injected is 20 to 22 tons per 10 meters of oil layer.

6. The method for developing deep extra-heavy oil reservoirs through in-situ heat generation and thermal drive pressure according to claim 1 or 2, characterized in that... In step 3, the nitrogen injection intensity is 800 to 850 standard cubic meters per meter of oil layer, and the injection time is 1 to 2 days.

7. The method for developing deep extra-heavy oil reservoirs through in-situ heat generation and thermal drive pressure according to claim 1 or 2, characterized in that... In step 4, hot air at 200°C to 250°C is used, and the injection intensity of the hot air is 500 to 600 standard cubic meters per meter of oil layer, with an injection time of 7 to 15 days.

8. The method for developing deep extra-heavy oil through in-situ heat generation and thermal drive as described in claim 6, characterized in that... In step 4, hot air at 200°C to 250°C is used, and the injection intensity of the hot air is 500 to 600 standard cubic meters per meter of oil layer, with an injection time of 7 to 15 days.

9. The method for developing deep extra-heavy oil reservoirs through in-situ heat generation and thermal displacement according to claim 1, 2, or 8, characterized in that... The crude oil viscosity of the deep extra-heavy oil is greater than 10,000 mPa·s, and the burial depth exceeds 2,500 m.

10. The method for in-situ thermal flooding and pressurization development of deep extra-heavy oil as described in claim 9, characterized in that... In step 4, the water injection rate is 20 to 23 cubic meters per day, the initial slug injection volume is 60 to 65 cubic meters, and a slug is injected every month, with the water volume increasing by 5 cubic meters each time.

Images