Diego Cueva - Academia.edu (original) (raw)
Papers by Diego Cueva
SPE Middle East Artificial Lift Conference and Exhibition, 2018
In Ecuador, the fields are getting more challenging in terms of reservoir depletion. Inchi field ... more In Ecuador, the fields are getting more challenging in terms of reservoir depletion. Inchi field is an example of such a field in which the production is normally obtained using electric submersible pumps (ESP), with a fast production decline. The wells start with production rates of 1,000 BOPD, and immediately production and pump intake pressure begin to decrease, thus requiring a secondary recovery technique such as water injection. However, the water to inject at required pressure is not always available, andspecial facilities are required to execute this operation, which increasescapital expenditures (CAPEX). Using a new approach that used the advantages of ESP sensors and operational flexibility, a production well was selected and converted to an injection well thus avoiding the high investments in surface facilities and making the secondary recovery a feasible option for low-producing wells. The Inchi A8 well on the Inchi A pad, was converted toa production injection well due to lack of available water in the field and production facilities. The paper includes an analysis of the completion design, ESP design, sensor installation modification for real-time injection pressure monitoring, ESP performance, injection stimulation, and results with the performance analysis for production recovery of nearby wells. The experience shared in this paper will let the reader understand the challenges for installation of a production injection well driven by the specific needs for and the advantages of injection pressure monitoring. After the installation of the production injection completion, the decrease in production and reservoir pressure stopped, the production in the field increased up to 166 BFPD in the Inchi 01 and Inchi A5 wells, the flowing bottomhole pressure has increased inan average of 100 psi in the wells Inchi 01 and Inchi A5, and in the well Inchi B6 the flowing bottomhole pressure is steady now closed to 600 psi (before was constantly decreasing). The injection pressure monitoring has been useful especially during the injection pressure tests performed by a testing unit, which allows to check the actual injection index of the reservoir. The savings associated with the installation of the production injection well include eliminating the need for additional surface facilities, a pipeline to bring water from the main station, and the construction of the water treatment plant in the location. This paper presents a design guideline for future production injection well applications, the benefits to in having a real-time injection pressure monitoring, and the way to usea conventional ESP discharge pressure to monitor the injection pressure and its performance.
ESP Water Injector Well with Injection Pressure Available for Real-Time Monitoring Recovered 30% of Production in Low Producer Wells, 2018
In Ecuador, the fields are getting more challenging in terms of reservoir depletion. Inchi field ... more In Ecuador, the fields are getting more challenging in terms of reservoir depletion. Inchi field is an example of such a field in which the production is normally obtained using electric submersible pumps (ESP), with a fast production decline. The wells start with production rates of 1,000 BOPD, and immediately production and pump intake pressure begin to decrease, thus requiring a secondary recovery technique such as water injection. However, the water to inject at required pressure is not always available, andspecial facilities are required to execute this operation, which increasescapital expenditures (CAPEX). Using a new approach that used the advantages of ESP sensors and operational flexibility, a production well was selected and converted to an injection well thus avoiding the high investments in surface facilities and making the secondary recovery a feasible option for low-producing wells. The Inchi A8 well on the Inchi A pad, was converted toa production injection well due to lack of available water in the field and production facilities. The paper includes an analysis of the completion design, ESP design, sensor installation modification for real-time injection pressure monitoring, ESP performance, injection stimulation, and results with the performance analysis for production recovery of nearby wells. The experience shared in this paper will let the reader understand the challenges for installation of a production injection well driven by the specific needs for and the advantages of injection pressure monitoring. After the installation of the production injection completion, the decrease in production and reservoir pressure stopped, the production in the field increased up to 166 BFPD in the Inchi 01 and Inchi A5 wells, the flowing bottomhole pressure has increased inan average of 100 psi in the wells Inchi 01 and Inchi A5, and in the well Inchi B6 the flowing bottomhole pressure is steady now closed to 600 psi (before was constantly decreasing). The injection pressure monitoring has been useful especially during the injection pressure tests performed by a testing unit, which allows to check the actual injection index of the reservoir. The savings associated with the installation of the production injection well include eliminating the need for additional surface facilities, a pipeline to bring water from the main station, and the construction of the water treatment plant in the location.
Assessment of the original artificial lift systems installed in place to determine better means t... more Assessment of the original artificial lift systems installed in place to determine better means to produce the existing assets and thus looking for ways to optimize and reduce lifting costs for the operator. Reciprocating rod lift systems with ultra long stroke mechanical pumping units were recommended and implemented to help achieve the desired flow rates. The existing artificial lift equipment was evaluated to determine if a more suitable alternative could be designed for the flow rates and depth encountered at the assets. This alternative included the use of reciprocating rod lift systems with an ultra-long stroke pumping unit, high strength sucker rods, custom tailored rod pump for the application, and automation equipment to match well inflow to displacement capacity throughout the pumping cycle. Three wells were converted from previous installations with hydraulic lift systems to ultra-long stroke reciprocating rod lift systems. Among the observed results upon the conversions were completed were: Reduced power consumption therefore a minor lifting cost per barrel, reduced work over costs due to nature of the interventions, and reduced surveillance expense with the use of automation equipment allowing the operator to monitor the wells remotely. The ultra-long stroke reciprocating rod lift systems increased the lifting efficiency, reduced production costs, and provided the operator with more flexibility for producing their asset.
Assessment of the original artificial lift systems installed in place to determine better means t... more Assessment of the original artificial lift systems installed in place to determine better means to produce the existing assets and thus looking for ways to optimize and reduce lifting costs for the operator. Reciprocating rod lift systems with ultra long stroke mechanical pumping units were recommended and implemented to help achieve the desired flow rates.
SPE Middle East Artificial Lift Conference and Exhibition, 2018
In Ecuador, the fields are getting more challenging in terms of reservoir depletion. Inchi field ... more In Ecuador, the fields are getting more challenging in terms of reservoir depletion. Inchi field is an example of such a field in which the production is normally obtained using electric submersible pumps (ESP), with a fast production decline. The wells start with production rates of 1,000 BOPD, and immediately production and pump intake pressure begin to decrease, thus requiring a secondary recovery technique such as water injection. However, the water to inject at required pressure is not always available, andspecial facilities are required to execute this operation, which increasescapital expenditures (CAPEX). Using a new approach that used the advantages of ESP sensors and operational flexibility, a production well was selected and converted to an injection well thus avoiding the high investments in surface facilities and making the secondary recovery a feasible option for low-producing wells. The Inchi A8 well on the Inchi A pad, was converted toa production injection well due to lack of available water in the field and production facilities. The paper includes an analysis of the completion design, ESP design, sensor installation modification for real-time injection pressure monitoring, ESP performance, injection stimulation, and results with the performance analysis for production recovery of nearby wells. The experience shared in this paper will let the reader understand the challenges for installation of a production injection well driven by the specific needs for and the advantages of injection pressure monitoring. After the installation of the production injection completion, the decrease in production and reservoir pressure stopped, the production in the field increased up to 166 BFPD in the Inchi 01 and Inchi A5 wells, the flowing bottomhole pressure has increased inan average of 100 psi in the wells Inchi 01 and Inchi A5, and in the well Inchi B6 the flowing bottomhole pressure is steady now closed to 600 psi (before was constantly decreasing). The injection pressure monitoring has been useful especially during the injection pressure tests performed by a testing unit, which allows to check the actual injection index of the reservoir. The savings associated with the installation of the production injection well include eliminating the need for additional surface facilities, a pipeline to bring water from the main station, and the construction of the water treatment plant in the location. This paper presents a design guideline for future production injection well applications, the benefits to in having a real-time injection pressure monitoring, and the way to usea conventional ESP discharge pressure to monitor the injection pressure and its performance.
ESP Water Injector Well with Injection Pressure Available for Real-Time Monitoring Recovered 30% of Production in Low Producer Wells, 2018
In Ecuador, the fields are getting more challenging in terms of reservoir depletion. Inchi field ... more In Ecuador, the fields are getting more challenging in terms of reservoir depletion. Inchi field is an example of such a field in which the production is normally obtained using electric submersible pumps (ESP), with a fast production decline. The wells start with production rates of 1,000 BOPD, and immediately production and pump intake pressure begin to decrease, thus requiring a secondary recovery technique such as water injection. However, the water to inject at required pressure is not always available, andspecial facilities are required to execute this operation, which increasescapital expenditures (CAPEX). Using a new approach that used the advantages of ESP sensors and operational flexibility, a production well was selected and converted to an injection well thus avoiding the high investments in surface facilities and making the secondary recovery a feasible option for low-producing wells. The Inchi A8 well on the Inchi A pad, was converted toa production injection well due to lack of available water in the field and production facilities. The paper includes an analysis of the completion design, ESP design, sensor installation modification for real-time injection pressure monitoring, ESP performance, injection stimulation, and results with the performance analysis for production recovery of nearby wells. The experience shared in this paper will let the reader understand the challenges for installation of a production injection well driven by the specific needs for and the advantages of injection pressure monitoring. After the installation of the production injection completion, the decrease in production and reservoir pressure stopped, the production in the field increased up to 166 BFPD in the Inchi 01 and Inchi A5 wells, the flowing bottomhole pressure has increased inan average of 100 psi in the wells Inchi 01 and Inchi A5, and in the well Inchi B6 the flowing bottomhole pressure is steady now closed to 600 psi (before was constantly decreasing). The injection pressure monitoring has been useful especially during the injection pressure tests performed by a testing unit, which allows to check the actual injection index of the reservoir. The savings associated with the installation of the production injection well include eliminating the need for additional surface facilities, a pipeline to bring water from the main station, and the construction of the water treatment plant in the location.
Assessment of the original artificial lift systems installed in place to determine better means t... more Assessment of the original artificial lift systems installed in place to determine better means to produce the existing assets and thus looking for ways to optimize and reduce lifting costs for the operator. Reciprocating rod lift systems with ultra long stroke mechanical pumping units were recommended and implemented to help achieve the desired flow rates. The existing artificial lift equipment was evaluated to determine if a more suitable alternative could be designed for the flow rates and depth encountered at the assets. This alternative included the use of reciprocating rod lift systems with an ultra-long stroke pumping unit, high strength sucker rods, custom tailored rod pump for the application, and automation equipment to match well inflow to displacement capacity throughout the pumping cycle. Three wells were converted from previous installations with hydraulic lift systems to ultra-long stroke reciprocating rod lift systems. Among the observed results upon the conversions were completed were: Reduced power consumption therefore a minor lifting cost per barrel, reduced work over costs due to nature of the interventions, and reduced surveillance expense with the use of automation equipment allowing the operator to monitor the wells remotely. The ultra-long stroke reciprocating rod lift systems increased the lifting efficiency, reduced production costs, and provided the operator with more flexibility for producing their asset.
Assessment of the original artificial lift systems installed in place to determine better means t... more Assessment of the original artificial lift systems installed in place to determine better means to produce the existing assets and thus looking for ways to optimize and reduce lifting costs for the operator. Reciprocating rod lift systems with ultra long stroke mechanical pumping units were recommended and implemented to help achieve the desired flow rates.